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191-044
• 4 i,'\\\\1/7- s� THE STATE P� j' �, arid_ �q � T� �f �\1� I7 /� / � CI 17,,er` �'/. �� �/' '-, t si}t 333 West Seventh Avenue GOVERNOR SEAN PARNELL Anchorage-, Alaska 59501-3572 '4 't" Main: 907.279.1 433 Op,ALAS � Fax. 90/.2/6./542 Sandra Hag and SCANNED AUG 0 6tiitV HI+0 g Regulatory Analyst XTO Energy 9127 South Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, & G Oil Pools, Middle Ground Shoal C21A-23 Sundry Number: 314-141 Dear Ms. Haggard: 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, ale4r144 /1----- Cathy P. Foerster Chair DATED this l7 a y of March, 2014. Encl. . RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 1 M4 APPLICATION FOR SUNDRY APPROVALS D�-S "3/(.g/ 20 AAC 25.280 O 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well Q . Change Approved Program 0 Suspend 0 Plug Perforations❑ Perforate o. Pull Tubing❑ /Tme Extension❑ Operations Shutdown 0 Re-enter Susp.Well 0 Stimulate 0 Alter Casing 0 Other 'Col tubing cleanout//l C461 2 f 2.Operator Name: 4.Current Wel Class: 5.Permit to Drill Number: 50'4 Or— XTO Energy , Exploratory ❑ Development ❑ 191-044• 3.Address: Stratigraphic ❑ Service 2 6.API Number. 9127 South Jamaica Street,Englewood,CO 80112 50-733-20129-02-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Perfing existing zone Will planned perforations require a spacing exception? Yes 0 No D• Middle Ground Shoal C21A 23 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 18756 • MGS E,F,G Oil pols . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,290 • 9,719 '12,286 9,717 None Fill @ 12,211' • Casing Length Size MD'. TVD Burst Collapse Structural Conductor 370 24 370 370 Surface 1438' 13-3/8" 1438' 1434' 2,730 psi 1,130 psi Intermediate 9320' 9-5/8" 9320' 7747' 6,330 psi 3,810 psi Production 2684' 7" 11410' 9204' 7240 psi 5410 psi Liner 1084' 5" 12290' 9719' 10,140 psi 10490psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11415-12280 • 9204-9709 2-7/8 605#L80 8RD EUE 11199 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"Baker SB-3 Packer and 2-7/8"BXE SSSV Packer at 11145'MD,9039'TVD and SSSV at 327'MD,327'TVD 12.Attachments: Description Summary of Proposal 2 • 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch 0 • Exploratory ❑ Stratigraphic D Development❑., • Service ❑ 14.Estimated Date for April 2014 15.Well Status after proposed work: Commencing Operations: Oil ❑✓ • Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sandra Haggard A�E�,ail Sandra Haaaardc xtoeneray.com Printed Name �— 7 Sandra Haggard Title 44 Signat�� Ph 303-397-3672 Date 14-Feb-14 11.446...... .4..... 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test [/ Mechanical Integrity Test p Location Clearance p Other: /V— ‘000S c. 40e S� / RBDM MAY 10 2014 Spacing Exception Required? Yes ❑ No [1 Subsequent Form Required: /D — t/eDt-/ APPROVED BY Approved by: ./-7-eti2 )v..._,„_2(Z.4„,.._ COMMISSIONER THE COMMISSION Date: 3 —/7 — / V it 3.(Hit #e //�� A A ' Submit Form and Form 10-403(Revised 10/2012) ApgroYeRpilit/^� i iLliAr�12 months from the date of approval. Attachments in Duplicate RECEIVED ENERGY MAR 0 2 Z u14 March3,2014 AO GCC Alaska Oil and Gas Conservation Commission Attn: John Norman,Commissioner 333 W. 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Form 10-403, Request for Sundry approval Objective: Coil Tubing Cleanout,Perforating and Acidize to Remove Scale Middle Ground Shoal#C21A-23 MGS Field Cook Inlet,Alaska API: 50-733-20129-02 PTD#: 191-044 XTO Energy Inc. hereby submits its Application for Sundry Approval for coil tubing cleanout, perforating and acidizing to remove scale deposits in the well. Attached is the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Proposed job procedure 3. Present wellbore schematics and deviation survey If you require additional information,please contact me at 303-397-3672 Sincerely, Sandra Haggard,Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer /To ERGY To: John Norman Guy Schwartz Victoria Ferguson CC: Romeo Perez Scott Griffith From: Ajibola Adeyeye Re: MGS C21A-23 (PTD: 191-044) Cook Inlet,Platform C Coil Tubing Cleanout and Acidize to Remove Scale/Re,.t r-( OBJECTIVE: The objective of XTO Energy proposed workover for MGS C21 A-23 producer well is to clean-out and acidize scale deposit in the tubing and across the production interval;the well has a history of scale deposit,requiring periodic cleanout.The plan includes mechanical cleanout of the tubing and liner via coil tubing,jet nozzle/mill.Afterwards,the well will be acidized to remove additional solids in the wellbore and across the production interval;diverting agent will be spotted to improve the distribution of acid into the perforations.A selected section of the existing production interval will be re-perforated and acidized to create flow paths around scaled perforations that did not adequately cleanout WELL HISTORY: C21A-23 was sidetracked out of the unproductive C11-23 wellbore in 1991;the seven layers of the Hemlock were underbalanced perforated via TCP and the well was not stimulated during the intial completion.The well IP'd at 152 BO,2 BW and 47 MCF. The well has a history of scale deposits in the tubing and across the production interval.Cleanouts was performed on the wells in the past done;cleanouts were done in 1999,2006 and 2011. In the past,the cleanout involve the use of xylene and lower concentrated hydrochloric acid.Recent cleanout were conducted by mixing xylene with 10%hydrochloric acid. MISCELLANEOUS: The AOGCC has granted XTO a waiver since 1999 concerning the BOPE stack since the rig's sub structure can only fit a double ram configuration and not a triple ram configuration.XTO was grandfathered a variance due to extensive knowledge of the mature Middle Ground Shoal Field and due to depleted reservoir pressure.XTO Energy is requesting the same variance for this workover. • r v, b " rhe anticipated start date for this workover is April 2014. Please contact me at 301-397-3606 with Pt; �0 any questions or concerns. a,ell �/ Sincerely, b° 7 'oil-Q11+ Bola Adeyeye Operations Engineer c✓( TO ENERGY MGS C21A-23 Workover Package for Coil Tubing Cleanout, Perforate and Acidize Operations Engineer: Bola Adeyeye Office: (303)3973606 Cell: (720)5391660 Well Identifier Well Name: MGS C21A-23 Permit to Drill Number: 191-044 API #: 50-733-20129-02-00 Objective Perform coil tubing cleanout to remove scale and other debris in the well. Soak well with acid, perforate existing zone and squeeze acid in the perforations; perform scale inhibitor squeeze. Background The C21A-23 was sidetracked out of the unproductive C11-23 wellbore in 1991. The hole was drilled with water based mud & encountered severe problems trying to get through the HC coal. The hole was drilled across the HC to HR without a problem and a 5" liner was cemented in place. The 7 layers of the Hemlock were underbalanced perforated. The well IP'd @ 152 BO, 2 BW & 47 MCF. In 1999, the job consisted of spotting 14 bbl of 7.5% HCL& 15 bbl xylene over the perfs with coil tubing. The 577' of net pay was then squeezed with only 33 bbl xylene. The production increased from 30 BO to 58 BO. The production steadily increased to ±100 BOPD over the next 2 years. In addition to the cleanout in 1999, other coil tubing cleanout and acidizing were performed in 2006 and 2011. One shot acid/DAD acid was used for cleanout; however, the production response after the cleanout was not up to expectation. In both cases (2006 and 2011), fluid similar to gel was flowback after acid is pumped into the well for cleanout. This might have been existing damage on the formation or might have occurred as a result of fluid incompatibility. 507' net perforations were created during the cleanout workover in 2011.Scale analysis indicates iron sulfide and calcium carbonate scale Precautions This well has always been a very low water producer(1%—25%) but has severe paraffin history, shallow and deep in the tubular. Must not use 'neat' acid, should be mixed with xylene. Subsurface safety valve is WL retrievable, will have to be pulled with the SL before CT rig up Workover History Activity Date Comments Well drilled (ST) 1991 Sidetracked out of C11-23 2" Gauge ring run June 1995 Tagged at 11,880', recovered lots of paraffin on tool Slickline Scratcher run May 1999 Hit paraffin high uphole (@228'), tag high at 12251' Coil Tubing Cleanout August 1999 Tag @ 12,242'.Spotted 'neat'xylene across perf. 30bbI uplift Coil Tubing Cleanout April 2006 Neat acid pumped to clean bridge.Severe fluid compatibility issues. Emulsion created, contaminated acid (bleach in FIW!!), Coil Tubing TCP &Acid Sept 2011 Used 10%DAD acid,squeezed into perf.Recovered thick fluid,500ft perfs added,no uplift Scratcher run on SL Nov 2013 Scale bridge appear to start at 11,568' Current Well Status Well is currently producing 20 bopd, 13 bwpd, 31 mcfd gas. Lift gas is continuously injected at 500 mcfd. Wellbore Construction Detail ID Drift Cap. Annular 100% 1.25 SF 100% 1.33 SF BbI/Ft Bbl/Ft Burst Burst Collapse Collapse Prd Tbg: 2-7/8", 6.5# L80@ 11,199' 2.441 2.347 0.00579 0.0302 13570 10856 13310 10007 Prd Liner—5", 18#, N80 @12,290' 4.276 4.151 0.0177 0.0107 10140 8112 10500 7894 Drilling Liner—7" 26# L80 and Intermediate Csg—9-5/8",43.5#&47#, L80 Surf Csg—13-3/8",54.5#,K55 @ 1,438' 12.615 12.459 0.1545 2730 2184 I 1130 849 Well Data Surface Casing: 13-3/8", 54.5#, K55, BTC. Set at 1438'. Cmt with 520 sx Intermediate Casing: 9-5/8", 43.5# &47# L80, LTC. Set at 9320', TOC at 8847' Drilling Liner: 7", 26#, L80 LTC. Set at 11,410'. Cmt with 2575 sx Production Liner: 5", 18# N80. Set at 12,290'. Cmt with 300 sx Top of liner @ 11206' PBTD: —12286' • Tubing: 2-7/8" 6.5#, 8rd L80. EOT at 11,199' Packer: Baker 'SB-3' permanent packer at 11,145' BHST: 240 F BHP: 3500 psi Smallest ID: Nipple milled to 2.330" ID at 11,187' Max Deviation: 55 deg at 12,290' Max DLS: 12.63 deg/100ft at 9,485' Other: Tagged high at 12,170' (scale), fish in hole (GLV dropped 12-31-95) MG.S C21A 23:Coil Tubing CIeonorut and Acrdiizing Procedure Vendor Outline Coil Tubing unit— Baker/BJ Services Josh Herald 907-398-8303 Chemical Supply— Baker Petrolite Clyde Willis 907-229-0052 Bits, Motors, BHA Josh Herald 907-398-8303 Crane Operator—All American Pete Dickinson 907-230-6541 Rousterbout & Drill Supv—All American Pete Dickinson 907-230-6541 GR—CCL Memory logging tool Steve Barow or Barry Milazzo Materials Required • 12000 gal 10 % HCI Acid (probably mixed with 25% Xylene) • 50 bbl Gel pill (supplied by Baker Hughes) • 100 bbl 3% KCI —Fresh Water (mixed out of fresh water) • 1000 bbl 3% KCI — FIW (fixed out of filtered inlet/sea water) • Nitrogen will be used as necessary to assist fluid cleanout • 660 gal of Baker Scale Inhibitor,this will be flushed with 3% KCI FIW Equipment Required • 1.5" Coil Tubing Unit C�1(,3, • 1.5" Pipe and blind rams, BOPE ✓ ,Lc‘� • 50 ft Lubricator � . � • Crane; provided by the platform • 2 PTS tanks—250 bbl each Acid Additives and Other Chemicals • 10 % HCI — Inorganic acid used to acidize the formation • 250 gpt Xylene (25%)—To dissolve and disperse solid petroleum residue • 12 gpt US-40— mutual solvent. Formation water wetting agent & reduce surface tension • 25 ppt Ferrotrol 300—acid treatment fluid to prevent precipitation of ferric hydroxide • 4 gpt Corossion Inhibitor—corrosion protection of tubular, casing & BHA • 20 gpt Ferrotrol 280L- acid treatment fluid to prevent precipitation of ferric hydroxide • 2.8 gpt FRW-16A— Friction reduction agent • 1.2 gpt Clay Master-5C—to prevent formation damage due to scale swelling • Soda Ash —to neutralize spent acid before sending to disposal well • H2S Scavenger—for cleanout returns that might have residual H2S MGS(2 IA 23:Coil Tubing Cleanout and/Iodizing Procedure , Well Schematic: C21A-23 PLF 12-29-11 ;(1.0 NERGY Present Completion — + KB: 35' MGS C21A-23 IIIIWater Depth: 73'MSL Cook Inlet,Alaska Tbg: 2 7/8"6.5#L80 8R EUE @ 11,199' Leg 4,Conductor 27 API No.:50-733-20219-02 J Set:7-25-91 Orig Well was C11-23 ,,/� +� Sidetracked:5-11-91 `�/ 2-7/8"BXE SSSV(2.313"ID)@ 327' J Item MD TVD Ptro Port Conductor:24",Set @ 370'. GLM#1 1839' 1828' 981 12 GLM#2 3677' 3398' 964 12 GLM#3 5454' 4742' 1000 16 GLM#4 6980' 5899' 948 12 J GLM#5 8124' 5802' 998 16 Surf Csg: 13-3/8"54.5#K55 BTC. GLM#6 9003' 7500' 998 16 Set @ 1,438'. Cmt'd w/520 sx. GLM#7 9667' 8000' 1100 20 J GLM#8 10396' 8506° 1099 20 GLM#9 11064' 8980' 1/4"Orifice J /id J Intermediate:9-5/8"L-80 LTC. Otis "XO"Sliding Sleeve @ 11,109' Window Milled @ 9320'. J , Anchor Seal Assy 11,144' Surf-4176':43.5# Baker SB-3 Packer 11,145' 4176-9320':47# '/ i Millout Extension 11,149' TOC±8847'. //� Nipple Milled to 2.30" ID 11,187' J ' WL Entry Guide 11,199' Drilling Liner: 7"26#L80 LTC. / // Set @ 11,410', TOL @ 8,726'. I i i Vir Cmt w/2,575 sk. e Production Liner:5"18#N80 FL4S. /4 Set @ 12,290'.TOL @ 11,206'. OrReperfed 11,415–12,176 @6 spf(Sept'11) Cmt w/300 sx. — Perfd @ 4 spf: 577'Net(2,308 holes) HC-HD: 11,415'-11,460' / HD-HE:11,490'-11,508' HE-HF: 11,564'-11,636' oA. HI-HK: 11,734'-11,764' HK-HN:11,786'-11,990' Fill @ 12,211'by CT(9-13-11) / itri OHN-HR:12,008'-12,108' Fish:GLV dropped 12-31-95 = HN-H 12, 12,176' HR-HZ:12,206-12,280' FILL: (None as of 10-17-10) --� PBTD: 12,286'MD / TD: 12,290'MD(9,719'TVD) W' !r. Production Trend (6 year) C21 A-23 HEMLOCK BBL 1.000 too 900 90 Boo Bo 700 70 600 60 500 iti ' � NI! 0010111 40 300 30 zoo 104)411641411��PIN 2:"16114� B ,d,BrVa 2/1 5H B/1 1111 2/1 511 011 1111 2/1 5/1 BH 11/1 2/1 5/1 811 1111 2/1 5/1 8/1 10/17113 Gas —oa —war• —w-,w M —Gr air-.. CO2 nrm —CO2,r,aaaar. moa.T.* —oa Tara. ---La-P•aommr. Production Chart (3 year) MCF BL 1000- C21A-23 HEMLOCK eloo 800- -80 600-• -BO 400 1 1.4° 1 200 -0400111Willfradlm1 • 20 2121111 511 711 911 1111 111 311 511 711 9/1 1111 111 311 5/1 711 911 11/1 2120/14 —■Gas —■Oil —■Water —•Water Inj —■Gas Injection 0 CO2 Prod —•CO2 Injection —•Gas Target —■Oil Target •-■LinePressure Clear Selections Lift Gas Injection and Production Pressure Chart 1,200 C21A-23 HEMLOCK 1,000- -25 800- -20 800- ` � -15 400 - - 10 200- r -5 01 / ♦0 2121111 511 711 911 1111 111 311 511 711 911 1111 111 311 511 711 911 1111 2120114 —II Casing Pressure II Tubing Pressure —•Annulus Pressure -•■SurfaceCasingPressure -'■InterCasingPressure - ■Down Hours - ■SoapStick clear Selections MGS C21A-23:Coil Tubing Cleanout and Acidizing Procedure Summary Procedure: 1. Nipple up the slickline unit, BOP and lubricator. Run into the well with the retrieving tool to pull the SSSV. Send the SSSV to the shop for inspection and redress, if necessary. 2. Move in the coil tubing unit and all associated equipment. Conduct safety meeting to review the daily work program and communicated associated risk with the entire crew. 3. Test BOPE, NU iniecti^n head and lubricator with the holding support of the crane ' '-- , ear 4. Pickle the coil to ing with acid and flush with 3% brine water, dispose appropriately 5. Pick up the roto-jet nozzle, CCL, GR memory tool (placed in a carrier) on 1.5" coil tubing and run rCe into the well. Cleanout the tubing and flag a depth for corelation. Download the log data. V- 6. Continue cleaning the production tubing, reduce speed upon approach of the end of tubing. Cleanout the inside of the 5" liner, and continue until approach a tagged depth. Spot acid across the production interval to soak any existing solid bridges. ilc.c.X 7. Perform an extra bottom to top of liner cleanout, record tagged depth during each downward trip. Pull the coil tubing out of the well. 8. If tagged high during the jet nozzle trip, pick up mill and motor. Run into well and additional solids in the liner. 9. Lay down the bit and motor. Pick up the perforating gun and run into well. Confirm the target ,Aperforating depth, drop the ball to fire the gun. Pull the gun assembly out of well and run the , next set guns to perforate the subsequent zones. I/''' 11/4j O. Pick up the roto-jet tool, run into the well. Pump the recommended acid design for the job.Shut in the coil tubing annulus and squeeze acid into the perforations. 11. Pull the coil tubing out of well and allow acid to soak for 24 hrs 12. Nipple down lubricator, BOPE and move the coil tubing over to the next well. 13. Resume the injection of lift gas on the well. Flow back well to the PTS tank, monitor flow and take periodic pH level of the fluid 14. Once the fluid pH is at recommended value, prepare scale inhibitor mixture and bullhead into the well to enable effective squeeze into the producing zones. 15. Resume lift gas injection and collect fluid samples periodically to measure the residuals Risks and Safety Considerations 1. All basic PPE's(FRC's, hard hat, safety glasses, steel toe boots) must be worn at all times, no exception.Additional PPE's might be required for personnel involved in other specific roles. 2. Pressure test will be required on the BOPE, surface lines and manifolds; refrain from the vicinity of the equipment during these tests. 3. Lubricator and injection head will be held with crane during the coil tubing work, personnel should stay clear of the lifting area as much as necessary. 4. Acid and other hazardous chemicals will be mixed in tanks and used during the cleanout process.All required PPE must be used when handling and mixing these chemicals; MSDS sheets must also be available within close proximity of these chemicals f""'✓fC.i. c._>.iA 2...t ('o;' Ti ping CIccanotut and Acid inq Procedure 5. Perforating guns will be used on the wells; manufacturer recommended precautions should be exercised for the handling and storage of these guns. Pre-Mobilization Plan for Production Operators ***Approximately 1 week prior to resuming coil tubing cleanout, shut off the lift gas supply into the annulus. Open the well to flow up the tubing to bleed-off effluent gas in the well. If well stop flowing, shut-in the well and periodically open to flow to bleed off head gas in the tubing. DETAILED PROCEDURE Major Notes ***Anticipated shut in pressure on this well is 3000psi. Production tree and wellhead are rated to 5000 psi. ***Do not include bleach or chlorinated chemical for the treatment of FIW ***Rock salt will be mixed with water/oil soluble gel as diversion agent during the acid squeeze ***The 'XN' nipple at the end of tubing was milled to 2.30" ID during prior cleanout ***Subsurface safety valve is wireline retrievable,will have to be pulled with the slickline before Coil tubing rig up on the well ***** Note: 3% brine water mixed from fresh water must be used as spacer fluid whenever acid is pumped. Refrain from allowing FIW to get in contact with the acid. ***** Mobilize, Set-up Equipment, Riq-Up 1. Rig up XTO Energy slickline unit, nipple up the WL lubricator and BOP. Pick up the retrieving tool and run into the well to pull the 2-7/8" BXE subsurface safety valve located at 327 ft. 2. Trip the wireline out of the well and lay down the tool.Visually inspect the SSSV and send onshore to the shop for re-dressing. 3. Move in All American Service crew to prepare the platform for the cleanout program, prep work will include insuring space for equipment location are cleared and measured for spotting ahead of time. Ensure crew is on-site at least 3 days prior to coil tubing mobilization. 4. Prior to staging equipment, conduct safety meeting to review the work program; potential hazards should be identified and communicated to the entire crew involved in the program 5. Stage the PTS tanks, move in the 1.5" Coil Tubing unit, lubricator, injector head, acid/other chemical vessels and all associated equipment required for the workover. Set-up the site, lay down and connect pipes to flowback/PTS tank and manifolds. Prepare fresh water mixed adequately with KCI to create 3% brine solution in the mud/PIT tank. - Two PTS tanks will be used on each platform during this program;this will enable adequate flowback of dirty fluid from multiple workover wells before sending offshore. Substantial cleanout of dirty fluid to the disposal well will help in minimizing the amount of sludge transported offshore. - Debris catcher/filter should be installed on the flowback line before the PTS tank to capture solids returns. Filter should be monitored and periodically emptied. - Ensure there are accessible valves on the flowback line to collect and monitor cleanout fluid on the upstream and downstream of the PTS tanks. Test BOPE, Pull SSSV 6. Ensure the master and wing valves are closed, re-check to insure the lift gas line is properly locked/tagged and closed. Nipple up pipe rams, blind rams, lubricator and injector head, hoist the lubricator and injection with the support of the crane. 7. Contact AOGCC 24 hours prior to BOP test,test BOPE to 250 psi and 5000 psi, low and high pressure for both shell and pipe tests. 8. Pump pipe volume of acid down the coil tubing to pickle and flush with 3% brine water that is conditioned from fresh water. Send the used acid and flush fluid to the PTS tank and be disposed appropriately. Cleanout with Roto Jet Nozzle,Acid Soak and Mill Scale 9. Pick up the roto-jet tool or regular jet nozzle, gamma ray and CCL memory tool, assemble the BHA. Memory tool will be installed in the carrier to enable flow across it. 10. Make-up BHA to the coil tubing connector and run into the well. Continue tripping into the well at 100fpm while washing out solids and other debris in the tubing with slick 3% KCI FIW and circulating at 1-2 BPM MGS C2IA 2,3: (321 1 uhinq C1e;anoiit and Acid izinq Procedure 3 11. Continue cleanout and monitor the annulus pressure and returns for difficulty in lifting fluid. Pump down nitrogen with the foaming agent as necessary to enhance the fluid flowback. Periodically collect samples on the flowback line and assess the effectiveness of the cleanout. 12. Continue cleaning the tubing while proceeding with caution through delicate sections such as the gas lift valves, sliding sleeve and the `XN' nipple (2.205" XN was milled down to 2.3" during prior cleanout operation). 13. Reduce the speed while approaching the end of tubing. Continue cleanout through the liner and proceed slowly until tagged. Flag a depth in the liner for correlation. - Pull up every 300 ft to ensure the coil tubing is not getting stuck, pump slugs of gel sweeps to improve the clean-ups. - If tagged high or unable to get to the bottom of the well, pump down 500 gal of acid and spot on top of the scale. Mill will be necessary for further cleanout 14. Make an extra up-down pass from the liner top at 40 fpm and clean additional scale on the perforations, continue downward till bottom is tagged. - If there are traces of barium sulfate in the scale (or radioactive tendency),the additional pass will help in assessing the success of cleaning out the deposits in the perforations,via the GR log. 15. Pull the roto-jet and logging tools out of the well. Download the log data and send to the production engineer. 16. If unable to get to bottom of the well with the roto-jet tool, pick up 1-11/16" motor 2.5" bit. Run into well at 80 fpm, mill out additional scale deposit in the liner Re-Perforating Exiting Producing Interval Via TCP The perforating gun will be put together at the Schlumberger's workshop into transportable sections and delivered to the platform; each run will consist of 40 ft gun with a 5 ft firing head. This will provide adequate space to trip and pull through the 50 ft lubricator A shear pin must be included on the BHA to release of the guns; in situation of last resort. The flagged depth on the CCL/GR log from earlier run will be used for depth correlation. 17. Hold a pre-job safety meeting before picking up the perforatingguns. Designate the essential personnel allowed on the rig floor while assembling and running the gun. All non-essential members must stay away from the location during the perforating events. od tdXlxr47 C,t`.fFtrm.d3 nod/4 rdurror)Procedure 9 18. Assemble to 40 ft gun and the firing head, run the coil tubing with connector through the lubricator to make-up to the gun assembly. Gradually pull out with the coil tubing to pull the gun while pulling up the lubricator with the crane. 19. Position the lubricator over the well;flange back the lubricator onto the BOP. Open the master valves and trip the perforating gun into the well. 20. Correlate and ascertain the depth to be perforated(refer to table 1), drop the ball and pump down to seat. Continue pumping to gradually pressure up to 3000 psi and engage the firing head, observe signals that indicates the gun is fired. Such sign includes sudden vibration on the lubricator/wellhead, and fluid surge out of the annulus. Table 1: Perforating gun data Run# Perforating Interval Gun length Comments 1 TBD 40 ft 1-9/16" or 2" HSD gc-11+6 2 TBD 40 ft 1-9/16" or 2" HSD // __pp 3 TBD 40 ft 1-9/16" or 2" HSD °"1147 21. Upon confirmation that the gun fired, carefully trip out while exercising some caution across the constricted depths (end of tubing, sliding sleeve and `XN' profiles). 22. Trip out to the surface; close the master valve and laydown the perforating gun. 23. Repeat steps 17 -21 for the second and third run of the 40 ft gun. Acid Squeeze 24. Pick up the roto-jet tool and run in at 100 fpm while circulating slick 3% KCI FIW. Continue cleaning the tubing and across the liner top,take returns up the CT annulus and circulate foamed nitrogen as necessary. 25. While at the topmost perforation (11415'), pump down 10 bbl 3% KCI—fresh water as spacer, 10 bbl 10%HCI acid and tail with another 10 bbl 3% KCI-fresh water.Slow down the pumping rate to1/4-%2 bpm as the acid approach the end of the tubing 26. Gradually proceed deeper into the liner while washing the perforation at this reduced rate, cleanout to the tagged depth. 27. Pull up the coil tubing to 11,840',the middle of the perforations. l f'a.S C,7I A...23 coil T ubin Tao ono ft nod/1c1 i ire r'ocedure 10 28. Pump fluid down the tubing while following the tabled sequence below. After 15 bbl of the 3% KCI—Fresh water in step 1 have exited the coil tubing, close the coil tubing annulus(refer to table 2). - Record time and rate when each fluid is pumped to estimate time of 3% KCI-fresh water at bottom of coil tubing. 29. Continue pumping the fluid as recommended to squeeze the acid into the formation. Table 1: Fluid Sequence for Well Circulation and Acid Squeeze Step Fluid Volume Comment/Purpose 1 3% KCI—Fresh Water 25 bbl Displacement of 3% KCI—FIW from bottom 2 Benzoic acid flakes Diverting agent to against flow into opened zones 3 10% HCI acid 2000 gal Acid stage 1 - squeeze into formation 4 Benzoic acid flakes Diverting agent 5 10% HCI acid 2000 gal Acid stage 2—squeeze into formation 6 Benzoic acid flakes Diverting agent 7 10% HCI acid 2000 gal Acid Stage 3—squeeze into formation 8 Benzoic acid flakes Diverting agent 9 10 % HCI acid 2000 gal Acid Stage 4—Squeeze into formation 10 Benzoic acid flakes Diverting agent 11 10% HCI acid 2000 gal Acid Stage 5—squeeze into formation 12 3% KCI —Fresh Water 15 bbl Spacer 30. Pull the coil tubing out of the well, lay down the roto-jet nozzle. Shut in the well, nipple down the coil tubing lubricator and BOPE. Move coil tubing over to the next well. 31. Allow acid to soak for 24 hours. Monitor and chart the tubing pressure. 32. After 24 hours and upon consultation with the production engineer, open well to flowback to the PTS tank and resume injection of lift gas to aid liquid unloading. Monitor returns and send flowback fluid into the disposal well. - pH of the flowback fluid must be measured and recorded,send record of the data to production engineer and Baker Hughes chemical contact before proceeding to the next step 33. Once the fluid PH is at recommended level, shut off lift gas supply. Scale Inhibitor Squeeze 34. Prepare scale inhibitor mixture. Engage the mud pump and bullhead the scale inhibitor as recommended in table 3. Flush with 3% KCI—FIW and shut in the well for 24 hours. 114' a 4 1A 2 Coil 1 aNn g mid A(i li iris Ixiocedu 1.t Table 3: Scale Inhibitor Squeeze-Fluid Sequence Fluid Type Volume (gal) Comment Mutual Solvent (WLC603) 660 gal Scale Inhibitor(SCW4004) 660 gal 3% KCI - FIW 85 bbl Displace Scale Inhibitor 35. After 24 hours and upon the approval of the production engineer, handover well to production team and resume injection of the lift gas. 36. Collect labelled bottle sample of fluid on an hourly basis, send sample Baker Hughes lab for further testing for scale inhibitor residuals. Well Directional Survey C Platform, Well C21 A-23 ND- Measured Angle Azimuth RKB TVD DLS deg/100 SVY# Depth deg deg ft Subsea ft Tie-In 265.00 0.25 46.00 265.00 160.00 0.34 1 295.00 0.42 96.00 295.00 190.00 1.07 2 325.00 0.28 69.00 325.00 220.00 0.71 3 356.00 0.18 48.00 356.00 251.00 0.42 4 386.00 0.17 319.00 386.00 281.00 0.82 5 416.00 0.30 285.00 416.00 311.00 0.62 6 446.00 0.62 277.00 446.00 341.00 1.09 7 478.00 0.88 279.00 477.99 372.99 0.82 8 509.00 0.97 278.00 508.99 403.99 0.29 9 539.00 1.07 275.00 538.99 433.99 0.38 10 571.00 1.58 276.00 570.98 465.98 1.60 11 651.00 2.23 280.00 650.93 545.93 0.83 12 680.00 3.28 302.00 679.90 574.90 5.08 13 696.00 3.22 301.00 695.87 590.87 0.52 14 722.00 3.07 301.00 721.83 616.83 0.58 15 786.00 2.87 300.00 785.75 680.75 0.32 16 817.00 2.95 298.00 816.71 711.71 0.42 17 847.00 3.18 295.00 846.66 741.66 0.93 18 878.00 3.55 292.00 877.61 772.61 1.32 19 909.00 3.92 289.00 908.55 803.55 1.35 20 939.00 4.52 288.00 938.46 833.46 2.01 21 969.00 5.02 285.00 968.36 863.36 1.86 22 1028.00 6.10 281.00 1027.08 922.08 1.94 MGS (-71 A A; :.0., ,...< +'mO Ci d-o ,( i'i;lc-Owing Procedure 12 23 1090.00 7.17 281.00 1088.67 983.67 1.73 24 1121.00 7.37 281.00 1119.42 1014.42 0.65 25 1208.00 7.08 277.00 1205.73 1100.73 0.67 26 1270.00 6.77 275.00 1267.27 1162.27 0.63 27 1314.00 6.58 275.00 1310.98 1205.98 0.43 28 1507.00 8.78 288.00 1502.25 1397.25 1.45 29 1596.00 9.83 291.00 1590.08 1485.08 1.30 30 1690.00 10.95 291.00 1682.53 1577.53 1.19 31 1781.00 12.20 293.00 1771.68 1666.68 1.44 32 1874.00 13.77 294.00 1862.30 1757.30 1.71 33 1962.00 15.33 296.00 1947.48 1842.48 1.86 34 2054.00 17.00 297.00 2035.83 1930.83 1.84 35 2146.00 19.00 297.00 2123.33 2018.33 2.17 36 2268.00 21.90 299.00 2237.63 2132.63 2.44 37 2359.00 23.90 299.00 2321.45 2216.45 2.20 38 2451.00 26.00 301.00 2404.86 2299.86 2.46 39 2542.00 27.80 301.00 2486.01 2381.01 1.98 40 2630.00 29.90 302.00 2563.09 2458.09 2.45 41 2724.00 32.10 304.00 2643.66 2538.66 2.58 42 2817.00 34.80 304.00 2721.25 2616.25 2.90 43 2909.00 37.27 304.00 2795.64 2690.64 2.68 44 3017.00 37.85 301.00 2881.26 2776.26 1.78 45 3047.00 37.25 300.00 2905.04 2800.04 2.85 46 3084.00 36.80 298.00 2934.58 2829.58 3.47 47 3115.00 37.35 297.00 2959.32 2854.32 2.63 48 3208.00 38.00 296.00 3032.93 2927.93 0.96 49 3333.00 38.40 297.00 3131.16 3026.16 0.59 50 3455.00 38.60 297.00 3226.64 3121.64 0.16 51 3578.00 39.40 298.00 3322.23 3217.23 0.83 52 3699.00 39.60 298.00 3415.59 3310.59 0.17 53 3849.00 40.30 299.00 3530.58 3425.58 0.63 54 4001.00 40.40 301.00 3646.43 3541.43 0.85 55 4153.00 40.50 302.00 3762.10 3657.10 0.43 56 4306.00 40.60 303.00 3878.35 3773.35 0.43 57 4457.00 41.00 303.00 3992.66 3887.66 0.26 58 4612.00 40.90 304.00 4109.73 4004.73 0.43 59 4769.00 41.20 305.00 4228.13 4123.13 0.46 60 4921.00 41.20 305.00 4342.50 4237.50 0.00 61 5073.00 41.30 305.00 4456.78 4351.78 0.07 62 5227.00 41.20 307.00 4572.57 4467.57 0.86 63 5382.00 41.40 308.00 4689.01 4584.01 0.44 t..tz r 2` 2..4: Coil I obina Ck.>oY?Clu and Acidrizlnq Procedure 13 64 5536.00 41.30 309.00 4804.62 4699.62 0.43 65 5690.00 41.30 310.00 4920.32 4815.32 0.43 66 5844.00 40.70 312.00 5036.55 4931.55 0.94 67 5999.00 41.00 313.00 5153.79 5048.79 0.46 68 6155.00 41.30 313.00 5271.26 5166.26 0.19 69 6309.00 41.60 314.00 5386.69 5281.69 0.47 70 6428.00 42.20 314.00 5475.26 5370.26 0.50 71 6489.00 42.50 315.00 5520.34 5415.34 1.21 72 6519.00 41.80 316.00 5542.58 5437.58 3.23 73 6550.00 40.70 318.00 5565.89 5460.89 5.54 74 6582.00 40.30 320.00 5590.23 5485.23 4.25 75 6613.00 40.10 322.00 5613.91 5508.91 4.21 76 6630.00 39.80 323.00 5626.94 5521.94 4.17 77 6771.00 38.70 328.00 5736.15 5631.15 2.37 78 6925.00 38.70 329.00 5856.34 5751.34 0.41 79 7081.00 38.40 330.00 5978.34 5873.34 0.44 80 7234.00 37.90 330.00 6098.66 5993.66 0.33 81 7382.00 37.20 332.00 6216.00 6111.00 0.95 82 7477.00 36.80 333.00 6291.87 6186.87 0.76 83 7634.00 36.90 334.00 6417.51 6312.51 0.39 84 7789.00 37.90 336.00 6540.65 6435.65 1.02 85 7909.00 38.90 337.00 6634.69 6529.69 0.98 86 7956.00 39.60 338.00 6671.08 6566.08 2.01 87 7970.00 39.60 338.00 6681.87 6576.87 0.00 88 8002.00 39.30 340.00 6706.58 6601.58 4.08 89 8034.00 38.60 341.00 6731.47 6626.47 2.94 90 8065.00 37.50 342.00 6755.88 6650.88 4.07 91 8096.00 36.70 344.00 6780.61 6675.61 4.67 92 8127.00 36.40 346.00 6805.51 6700.51 3.96 93 8158.00 36.30 347.00 6830.48 6725.48 1.94 94 8189.00 36.60 350.00 6855.42 6750.42 5.83 95 8217.00 36.80 351.00 6877.87 6772.87 2.25 96 8317.00 36.90 356.00 6957.91 6852.91 3.00 97 8440.00 37.80 357.00 7055.68 6950.68 0.88 98 8565.00 37.70 359.00 7154.52 7049.52 0.98 99 8666.00 37.60 3.00 7234.5 7129.5 2.42 100 8809.00 37.80 3.00 7347.65 7242.65 0.14 101 8879.00 37.90 3.00 7402.92 7297.92 0.14 102 9024.00 38.40 6.00 7516.96 7411.96 1.32 103 9178.00 39.10 7.00 7637.06 7532.06 0.61 104 9325.00 39.50 9.00 7750.82 7645.82 0.90 fVIG.5 (21A 23:(:'aril.Cubing CGonota and Acldizinq Procedure 14 i I 105 9360.00 39.90 14.00 7777.76 7672.76 9.19 106 9424.00 40.60 10.00 7826.61 7721.61 4.18 107 9485.00 43.00 21.00 7872.14 7767.14 12.68 108 9507.00 43.80 20.00 7888.13 7783.13 4.79 109 9541.00 44.70 20.00 7912.48 7807.48 2.65 110 9572.00 44.50 21.00 7934.56 7829.56 2.36 111 9603.00 45.20 22.00 7956.53 7851.53 3.21 112 9634.00 46.00 21.00 7978.22 7873.22 3.46 113 9666.00 47.00 22.00 8000.25 7895.25 3.86 114 9898.00 46.70 21.00 8158.92 8053.92 0.34 115 10423.00 44.50 30.00 8526.61 8421.61 1.29 116 10740.00 45.00 34.00 8751.78 8646.78 0.90 117 10800.00 45.10 35.00 8794.17 8689.17 1.19 118 10827.00 44.90 35.00 8813.26 8708.26 0.74 119 10858.00 45.00 36.00 8835.2 8730.2 2.30 120 10891.00 44.40 37.00 8858.66 8753.66 2.80 121 10920.00 43.60 38.00 8879.52 8774.52 3.65 122 10933.00 43.67 38.00 8888.93 8783.93 0.54 123 10948.00 43.60 38.00 8899.78 8794.78 0.47 124 10964.00 43.50 39.00 8911.38 8806.38 4.35 125 10974.00 44.30 39.00 8918.58 8813.58 8.00 126 10991.00 45.50 40.00 8930.63 8825.63 8.19 127 11023.00 46.40 39.00 8952.88 8847.88 3.60 128 11038.00 46.40 38.00 8963.22 8858.22 4.83 129 11055.00 46.90 38.00 8974.89 8869.89 2.94 130 11070.00 47.40 38.00 8985.09 8880.09 3.33 131 11086.00 47.82 38.00 8995.88 8890.88 2.62 132 11091.00 47.60 38.00 8999.24 8894.24 4.40 133 11101.00 47.60 38.00 9005.99 8900.99 0.00 134 11118.00 47.60 38.00 9017.45 8912.45 0.00 135 11133.00 47.70 37.00 9027.55 8922.55 4.97 136 11149.00 48.00 36.00 9038.29 8933.29 5.00 137 11164.00 48.00 37.00 9048.33 8943.33 4.95 138 11181.00 48.50 37.00 9059.65 8954.65 2.94 139 11212.00 49.10 38.00 9080.07 8975.07 3.10 140 11245.00 50.00 40.00 9101.48 8996.48 5.36 141 11326.00 50.80 43.00 9153.12 9048.12 3.02 142 11619.00 54.00 47.00 9331.91 9226.91 1.54 143 11830.00 54.50 53.00 9455.26 9350.26 2.32 144 12290.00 55.00 64.00 9721.29 9616.29 1.95 MGS C21A-23:Coil Tubing Cleanout and Acidizing Procedure OFFSHORE Well Head Rig Up Vl 17 BAKER aa 44\ HUGHES a / y it I4/4 96"Gooseneck o 1f -IF , i- ,....4,-, i S&S 800L Injector Head .i Ir Hydraulic Stripper 4 1/6" 10K 4 Crossover4 1/16"10K x 5 1/16"10K 5 1/16"10K Lubricator -10 ft i I 5 1/16" 10K Flow Cross-2 ft 4 Crossover 5 1/16" 10K x 4 1/16" 10K --- a(5 )•• ..( 4 1/16"15K Combi BOPS Blind/Shear Ram (1 ■I) e'Ca Pipe/Slip Ram v ..' i= .'' "J %.1.04 4 1/16" 10K Flow Cross 1'j; H 4—4 1/16" 15K Blind/Shear Ram STATE OF ALASKA ALASKAIL AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon H Repair Well U Plug Perforations H Stimulate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time xtension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate isi Re -enter Suspended Well ❑ 2. Operator XTO Energy Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 191 -044 3. Address: 200 N. Loraine, Suite 800, Midland, Tx 79701 Stratigraphic III Service ❑ 6. API Number: 50- 733 - 20129 -02 r ' 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 18756 d Middle Ground Shoal #C21A -23 9. Field /Pool(s): • MGS E, F, G Oil Pool 10. Present Well Condition Summary: Total Depth measured 12,290 feet Plugs measured feet true vertical 9,719.00 feet Junk measured feet Effective Depth measured 12,211 feet Packer measured feet true vertical 9,676 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 370 24 370 370 Surface 1438 13 -3/8 1438 1,434 2730 1130 Intermediate 9320 9 5/8 9320 7,747 6330 3810 Production 2684 7 11410 9204 7240 5410 Liner 1084 5 12290 9,719 10140 ' Perforation depth Measured depth 11415 -12176 feet JAN V 3 2012 True Vertical depth 9206 -9655 feet k L-,916 Lulls. Comnissign tmcilome Tubing (size, grade, measured and true vertical depth) 2- 7/8 ",6.5#,L -80 11199 MD . Packers and SSSV (type, measured and true vertical depth) Baker 7" SB3 Perm 11145 SSSV 327 11. Stimulation or cement squeeze summary: Intervals treated (measured): See attached report. # ,,f/l��uu 11,415' - 12,176' SLANNE -1 .i ; ‘ zuk. Treatment descriptions including volumes used and final pressure See attached daily report. 163 bbls 10% DAD Acid (10% HCL + 25% Xylene). Final Rate 0.6 BPM © 4050 psi. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 46 53 19 470 90 Subsequent to operation: 17 86 11 550 90 1 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Development Isi r Service ❑ Stratigraphic ❑ Daily Report of Well Operations Attached 15. Well Status after work: Oil . El Gas U WDSPL H GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 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: 311 -231 Contact Paul Figel, Engr. - Tel. No. 432 - 620 -6743 Printed Name Maria Perez /1/2 Phone Title Regulatory Analyst Signature /��� , � c. � / 432 - 620 -432f Date 12/29/2011 te9/2- R9 DMS JAN 0 4 2 012 • Z ! Form 10 -404 Revised 10/2010 � 10 Submit Original Only , • • 0 ItT E PLF 12 -29 -11 N. E R G Y Present Completion r wiro KB: 35' MGS C21A -23 ■ Water Depth: 73' MSL Cook Inlet, Alaska Tbg: 2 7/8" 6.5# L80 8R EUE @ 11,199' Leg 4, Conductor 27 A PI No.: 50- 733 - 20219 -02 Set: 7 -25 -91 Orig Well was C11 -23 „ 94, 2 -7/8 BXE SSSV 2.313 ID) 327' ,,,,,, Sidetracked: 5 -11 -91 ( )@ 4 0 Item MD TVD Ptro Port Conductor: 24" , Set @ 370'. GLM #1 1839' 1828' 981 12 GLM #2 3677' 3398' 964 12 GLM #3 5454' 4742' 1000 16 GLM #4 6980' 5899' 948 12 GLM #5 8124' 5802' 998 16 Surf Csg: 13 -3/8" 54.5# K55 BTC. GLM #6 9003' 7500' 998 16 Set @ 1,438'. Cmt'd w/ 520 sx. GLM #7 9667' 8000' 1100 20 GLM #8 10396' 8506' 1099 20 GLM #9 11064' 8980' 1/4" Orifice 0 . p Intermediate: 9-5/8" L-80 LTC. Ot "XO" Sliding Sleeve @ 11,109' Window Milled @ 9320'. Anchor Seal Assy 11,144' Surf - 4176' : 43.5# Baker SB -3 Packer 11,145' 4176' -9320' : 47# Millout Extension 11,149' TOC ±8847'. f Nipple Milled to 2.30" ID 11,187' oe WL Entry Guide 11,199' Drilling Liner: 7" 26# L80 LTC. 0 0,1: i Set @ 11,410', TOL @ 8,726'. ■ ■■ • Cmt w/ 2,575 sk. fi'" --= 111110-='011/1 00 • 0$ Production Liner: 5" 18# N80 FL4S. 0,p P;04 Set @ 12,290'. TOL @ 11,206'. Reperfed 11,415 — 12,176 @6 spf (Sept '11) Cmt w/ 300 sx. Perf d @ 4 spf: 577' Net (2,308 holes) HC-HD: 11,415'-11,460' lirj HD HE:11,490'- 11,508' H E -H F: 11, 564' -11, 636' 4 __ ___ HI -HK: 11,734'- 11,764' Fill @ 12,211' by CT (9- 13 -11) % HK -HN:11,786'- 11,990' H N -H R:12,008'- 12,108' Fish: GLV dropped 12 -31 -95 HN- HR:12,140'- 12,176' ,. . ','`-3t:<'" HR -HZ: 12,208' - 12,280' FILL: (None as of 10- 17 -10) PBTD: 12,286' MD F-44r:,,, TD: 12,290' MD (9,719' TVD) /l!/ • drA XTO Midand Alaska OCD Report Run Dates: 9/10/2011 - 12/29/2011 Report for: Midland • 'TO is i C i Engineer: Paul Figel Well Name: Middle Ground Shoal C29A -23 API: 5073320129 State: Alaska County: Kenai Peninsula Spud Dt: [Objective: Slickline First Reported: 09/08/2011 Finaled: 09/08/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: Activity Date: 09/08/2011 Report Date: 09/10/2011 Depth End: Footage: Days from Spud: Operation Summary: • - Rig up wireline and pressure test lubricator. - Run in hole with 2.44" scratcher to 292' WLM tag SV. No problems. Pull out of hole. - Run in hole with 2.5" GS & prong to 292' WLM. Latch and pull Otis BXE ball valve. Pull out of hole with safety valve. - Run in hole with 2.44" scratcher. Tagged fill at 12,245' WLM. No problems. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and ML pulling tool to 11,056' WLM. Latch & pull orifice valve. Pull out of hole. ✓ - Rig down wireline. Objective: Coil Tubing Perf & Stim Treat First Reported: 09/12/2011 Finaled: 09/20/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: 1104410 Activity Date: 09/12/2011 Report Date: 09/13/2011 Depth End: Footage: Days from Spud: Operation Summary: MIRU SLB CTU. Clean out pits. Build 400 bbis 3% KCL fluid, rig up back flow tank and iron. • [Activity Date: 09/13/2011 Report Date: 09/14/2011 Depth End: Footage: Days from Spud: Operation Summary: MIRU SLB CTU, rig up backflow tank and iron. Test BOPE 250/4500psi Good Test. Make up 2.30 od mill and motor, RIH, Tag XN nip at 11,171' CTMD mill nirt pmfi�f XN nip to 2.30, RIH tag 12242' CTMD(PBTD) POOH with mill assy. lay down mill and mtr. M/U Expro Memory GR/CL tooTw"ith circ port. fluid pack test lube, open well RIH W/ ogg1 tools. 'Activity Date: 09/14/2011 Report Date: 09/15/2011 Depth End: Footage: Days from Spud: Operation Summary: Report Run on: 12/29/2011 Page 1 of 7 WellView XTO Midand Alaska OCD Report Run Dates: 9/10/2011 - 12/29/2011 Report for: Midland "TO RIH w/ Expro memory GR /CCL (one tag @ xn nip. 11,172' then smooth) Tag 12,225 several attempts unable to pass 12,225' (with 1,500 Ibs set down counter 12,229') Start logging up 30fpm F/ 12,228' to 11,000' (flag coil 11,250') POOH with logging tools. Close in well, rig down memory log sub, set injector aside, monitor well for pressure, open to flow back monitor for flow, down load data from log. Correlate log, PJSM, well still static. Pick up perf guns (42 guns 2 -1/8" RDX with 6spf and 60 degree phasing) PJSM with night crew, pick up firing head xo's and swivel, pick up injector make up coil to guns, stab lube, pressure test tube ok zero counter with coil connector tagged up at stripper(EOG 876.72') lower in hole 50' close rams, fluid pack riser test tube 1500psi, bleed off, open rams, Start in hole. Unable to pass 72' (E09 949'�work to pass attempt pump down back side, no success getting over pull, pipe came out stripper and was collapsed. Monitor well, confer with SLB supervision in town about options. PJSM Unstab lube, pull up with crane pulling guns injector and tube, tubing colappsed aprox 25' from stripper down in hole pulled up to rounded pipe at lube connection.Set pipe slips, and pipe rams. Cut coil past collapsed tubing. Prep and lower collapsed coil tubing cutting off to round section coil. Operation Remarks: Platform fire alarm 0130hrs At 1545 hrs.disscussed with Mr. Jim Regg of AOGCC possabilty of changing pipe sizes of coil tubing to finish work on C21 -23, so changing rams and testing BOPE. Will keep him updated daily. Activity Date: 09/15/2011 Report Date: 09/16/2011 Depth End: Footage: Days from Spud: Operation Summary: Cut off colapsed coil lowering with coil unit. Dress cuts and install dbl rolion connector. Pull test, open rams and slips. restab lube, pull guns up, tag coil connector on stripper, lower 10', PJSM, unstab lube, remove firing head, rig injector and lube aside, lay down perf guns. pick up injector and lube stab, blow down coil with N2 shange out coil spools change BOP componets for 1.5" pipe and change gripper blocks and stripper on injector, stab pipe, install coil connector make up lube. make up test assy stab lube. Fill coil with water W/ 3% kci. Test BOPE 250/4200 psi repair failures.(tested gas alarms while picking up injector head) Operation Remarks: Discussed with MR. Jim Regg of AOGCC status of changing out coil and up coming BOP test. Arrange travel for inspector Mr. Lou Grimaldi for test. Activity Date: 09/16/2011 Report Date: 09/17/2011 Depth End: Footage: Days from Spud: Operation Summary: Test BOPE 250/4200psi repair leaks.(BOP test witnessed by Mr. Lou Grimaldi of AOGCC) Pop off, remove test assy. Make up Expro memory GR /CCL. RIH w/ memory log while circ 0.3 BPM 3% FIW. Tagged up @ 12,211'. PUH while logging @ 30 fpm to 11,000'. RIH to 11,300' and flagged CT. POOH w/ log. correlate Togs, PJSM, pick up guns, Pick up injector, and lube, make up firing head. make up coil stab on. Zero coil with stripper tag, lower 55', pipe in rams, close rams,test lube T/ 1500psi open rams, RIH to flag on coil, correlate depth, RIH 10' past shooting depth, load and drop 7/16" steel ball, pull up to shooting depth while pumping ball down 1.5bpm 2900psi for 18bbis 411 slow pump down .5bpm 425psi, ball on seat, pressure up to 3000psi. Guns fired with good indication. POOH with guns. Operation Remarks: Perf guns 2 -1/8" RDX 6spf with 60 degree phasing. Perf Intervals HC - HD 11415'- 11460' HD - HE 11490' - 11508' HE - HF 11564' - 11636' HI - HK 11734' - 11764' HK - HN 11786' - 11990' HN - HR 12008' - 12108' HN - HR 12140'- 12176' [Activity Date: 09/17/2011 Report Date: 09/18/2011 Report Run on: 12/29/2011 Page 2 of 7 WellView XTO Midand Alaska OCD Report Run Dates: 9/10/2011 - 12/29/2011 Report for: Midland i :Nti11t Depth End: Footage: Days from Spud: Operation Summary: POOH with perf guns, PJSM, fill hole, unstab lube, lay down firing head, set lube and injector aside. Lay down perf guns. pick up injector and lube, make up bha with 1.75" OD jet swirl stab on fluid pack and pressure test lube to 4500psi bleed off, open well, RIH T/ 12180' stir acid in tanks. PJSM, pump 15bbls 10% DAD acid and lay in F/ 12180' T/ 11400' soak 30 min, pump out with 10bb1 sweep, displace with 2% kcl, and 10% DAD acid with acid at wash nozzle, close and inject 10% DAD acid, making passes F 12180' T/ 11400' Initinal .75bpm 2800psi slowly climbing and average .25bpm At 2130hrs rate .55bpm 4200 psi. wellhead pressure 3900 psi. with 148bbIs pumped pressure spike up 4500psi, with pump off slow bleed,work pressure to determine if nozzle plugged getting spikes on circ pressure and wellhead pressure, steady decline. Bleed wellhead pressure F /1600psi T/ 500psi (bleed 4 bbls) bring on pump press to 4000psi with no change in wellhead pressure. POOH with coil. [Activity Date: 09/18/2011 Report Date: 09/19/2011 Depth End: Footage: Days from Spud: Operation Summary: POOH with coil, shut in well, attempt to pump through coil - no joy, flush riser through kill line with soda ash FIW, bleed off. PJSM pop off, remove BHA no obstructions. Stab lube with open ended coil, circ soda ash FIW down coil with returns to flow back tank, initinal .2bpm, 4200psi switch to 2% FIW final circ 2.5bpm 1300psi clean • returns.PJSM, line up pump remaining acid from all tanks to flowback tank and inject down disposal well with mud pump. flush acid lines. Unstab lube, make up BHA stab lube, fluid pack and pressure test to 4200psi., Open well, RIH 80fpm, pump.25bpm. With scale inhibited (Nalco EC6079A) 2% FIW no friction reducer exiting nozzle 11,300' shut in well and inject 125 bbls initinal lbpm 3500psi, and final .58bpm, circ pressure 4860psi and wellhead of 4050psi, making 2 passes from 11400' to 12180' at 15fpm. POOH with coil, continue pumping maintaining wellhead pressure.Shut in well with 500psi, blow down coil with N2, rig down coil tubing equipment. Operation Remarks: Rig up P u slick line, R attempt to set orifice valve in GLM at 11056' WLM 'Activity Date: 09/19/2011 Report Date: 09/20/2011 Depth End: Footage: Days from Spud: Operation Summary: Slick line attempt to set orifice valve in GLM at 11056' WLM, POOH clean tools, make second attempt unscussful POOH, found seals on orifice valve swollen. Rig down slickline lube, rig up back flow line, test 1000psi, Production start gas lift @ 1115hrs. on 9 -19 -11 Operation Remarks: 9 -20 -11 @ 0600 hrs. 636bb1s recovered from well PH -6 890 csg pressure 9 -21 -11 @ 0600 hrs. 881 bbls recovered from well PH -5 840 csg pressure, @ 1800 with 961 bbls recoverd Production shut down gas lift alow to bleed off to header pressure @0001 hrs9 -22 -11 pack well to 900psi with gas, 9 -22 -11 @ 0600hrs 961bbIs recoverd, well shut in tbg and ann. 900psi, open well to flow back tank, 1800hrs shut in well 1041bbls total recoverd PH 3 secure tree 10 -8 -11 Production start gas lifting to flowback tank 0830hrs (previous total, 1041bbls) • 10 -9 -11 @0530 1172bbIs total recoverd from well. PH - 3.5 csg - 680psi 10 -10 -11 @0530hrs 1204bbIs total recoverd from well, PH - 3.5 Csg- 780psi 10 -11 -11 @0530hrs 1232bb1s total recoverd from well, PH 8 Csg 860 10 -12 -11 @0530hrs 1336bb1s total recoverd from well, PH 6.5 Csg 840 10 -13 -11 @0530hrs 1343bb1s total recoverd from well PH 4.5 csg 860 10 -15 -11 @0530hrs 1362bb1s total recoverd from well PH 3.5 csg 860 10 -16 -11 @0530hrs 1392bb1s recoverd PH 4 csg 870 [ Date: 12/23/2011 Report Date: 12/24/2011 Depth End: Footage: Days from Spud: Operation Summary: Well Test: 17 BOPD, 11 BWPD & 86 MCF. Lift gas @ 519 MCF w/ CP © 550 psi. FINAL REPORT. Report Run on: 12/29/2011 Page 3 of 7 WellView XTO Midand Alaska OCD Report Run Dates: 9/10/2011 - 12/29/2011 Report for: Midland L \ [Objective: Slickline First Reported: 09/19/2011 Finaled: 09/19/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: Activity Date: 09/19/2011 Report Date: 09/19/2011 Depth End: Footage: Days from Spud: Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with Daniels 2 -1/2" KOT and %d' OV to # 9 GLM at 11,056' WLM. Tools fell as slow as 22' FPM and pick up weights are high doe to thick fluids post CTU work. Tried for one hour but could not locate pocket. Pull out of hole. - KOT had scale cuttings in it and was jammed. Redressed tools. • - Reran Daniels 2 -1/2" KOT and 1 /1" OV to # 9 GLM at 11,056' WLM. Tried % hour to locate with no success. Pulled up hole to # 8 GLM and was able to get KOT to trip. Go back down hole to # 9 GLM at 11,056'. Was able to sit down in pocket. Jarred down 45 minutes trying to set OV. Due to extremely poor jar action in thick fluid, was not able to set valve. Pull out of hole. - Out of hole & inspect tools. More scale cuttings and the packing on the OV was swelled up from Xylene. - Well will have to be put to flow back tank for some period of time for fluid clean up before we will be able to set this OV. - Rig down wireline. 'Objective: Slickline First Reported: 10/10/2011 Finaled: 10/10/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: 'Activity Date: 10/10/2011 Report Date: 10/16/2011 Depth End: Footage: Days from Spud: Operation Summary: - Tested well at 84 ppm post acid job. - Pump down 100 BBL's of FIW with H2S scavenger. - Rig up wireline and pressure test lubricator. - Run in hole with Daniels 2 -1/2" KOT and %" OV to # 9 GLM at 11,056' WLM. Located & set orifice valve. Pull out of hole. - Rig down wireline. - Put well back to PTS tank for flow back. [Objective: Slickline First Reported: 10/13/2011 Finaled: 10/13/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: Activity Date: 10/13/2011 Report Date: 10/16/2011 Depth End: Footage: Days from Spud: Report Run on: 12/29/2011 Page 4 of 7 WellView XTO Midand Alaska OCD Report Run Dates: 9/10/2011 - 12/29/2011 Report for: Midland "TO Operation Summary: - Well had been flowing back to PTS tank post CTU acid / perf job. Well quit making fluid and was U- Tubing dry gas. - Rig up wireline and pressure test lubricator. - Run in hole with tandem AKS Labs pressure / temperature gauges taking one minute samples 50' above & below all 9 GLM's. Pull out of hole. - Down load gauges. Data good. Found # 5 GLV to have severe leak / failure. Contacted Pollard Wireline for replacement GLV. - Secure equipment and SDFN. L` [Activity Date: 10/14/2011 Report Date: 10/16/2011 Depth End: Footage: Days from Spud: Operation Summary: - Received replacement # 5 GLV from Pollard Wireline. - Rig up wireline and pressure test lubricator. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool. Located & was able to sit down on # 5 GLV at 8117' WLM but could not latch GLV. Made several attempts to latch up but sheared pulling tool in doing so. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool. Located & was able to sit down on # 5 GLV at 8117' WLM but could not latch GLV. Made several attempts to latch up without getting too rough on tools. Still could not latch GLV. Pull out of hole. ML pulling tool is not sheared. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" Carrico JDC pulling tool. Located & was able to sit down on # 5 GLV at 8117' WLM but could not latch GLV. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" x 7/8" latch Bowen style grapple overshot. Located & was able to latch # 5 GLV. Jarred medium jar licks 1 /2 hour and pulled # 5 GLV. Pull out of hole. - Out of hole with GLV. Fish neck on BK latch was completely rounded off. - Run in hole with Daniels 2 -1/2" KOT and new # 5 GLV & new BK latch to 8117' WLM. Locate & set. Pull out of hole. - Rig down wireline. - Put well back to PTS tank for flow back. [Objective: Slickline First Reported: 10/18/2011 Finaled: 10/18/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: [Activity Date: 10/18/2011 Report Date: 10/20/2011 ` • Depth End: Footage: Days from Spud: Operation Summary: - Rig up wireline and pressure test lubricator. - Run in hole with AKS Labs tandem pressure / temp instruments. Made 10 minute stops above and below all 9 GLM's. Pull out of hole. - Download gauge. Data good. # 2 is definitely leaking and # 7 looks questionable. Order replacement GLV's from Pollard. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool to 9661' WLM. Latch & pull # 7 GLV. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool to 3662' WLM. Latch & pull # 2 GLV. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and new # 2 GLV to 3662'. Locate & set. Pull out of hole. - Run in hole with Daniels 2-1/2" KOT and new # 7 GLV to 9661'. Locate & set. Pull out of hole. - Rig down wireline. - Put well back to PTS tank for flow back. Report Run on: 12/29/2011 Page 5 of 7 WellView XTO Midand Alaska OCD Report Run Dates: 9/10/2011 - 12/29/2011 Report for: Midland F ;\E.R( [Objective: Slickline First Reported: 10/26/2011 Finaled: 10/27/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: [Activity Date: 10/26/2011 Report Date: 10/28/2011 Depth End: Footage: Days from Spud: Operation Summary: 10 -26 -2011 - Rig up wireline and pressure test lubricator. - Equalize tubing & casing at 880 PSI. • - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool to 10,393" WLM. Latch & pull # 8 GLV. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and new # 8 GLV to 10,393'. Locate & set. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool to 8997" WLM. Latch & pull # 6 GLV. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and new # 6 GLV to 8997'. Locate & set. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool to 6970" WLM. Latch & pull # 4 GLV. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and new # 4 GLV to 6970'. Locate & set. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and 1 -1/4" ML pulling tool to 5440' WLM. Latch & pull # 3 GLV. Pull out of hole. - Run in hole with Daniels 2 -1/2" KOT and new # 3 GLV to 5440'. Locate & set. Pull out of hole. 10 -27 -2011 - Rig down wireline. - Put well back to PTS tank for flow back. - Well is having trouble unloading due to back pressure in PTS tank. - PH is at 5 and over 1600 BBL's have been recovered so far. - Decision was made to put well to production header. [Objective: Slickline First Reported: 11/05/2011 Finaled: 11/05/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE #: [Activity Date: 11/05/2011 Report Date: 11/05/2011 Depth End: Footage: Days from Spud: Operation Summary: Report Run on: 12/29/2011 Page 6 of 7 WellView XTO Midand Alaska OCD Report Run Dates: 9/10/2011 - 12/29/2011 Report for: Midland E N F : l z - Rig up wireline and pressure test lubricator. - Run in hole with full drift 2 -1/2" scratcher. Scratched area of safety valve nipple at 292'. Pull out of hole. - Purge 1 gallon of control line fluid. - Run in hole with 2 -1/2" Halliburton BXE Safety Ball Valve to 292' WLM. Locate & set. Pull out of hole. - Performed state closure test on safety valve. Test good. - Rig down wireline. End of Report • Report Run on: 12/29/2011 Page 7 of 7 WellView • S TATE AILAZU SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1IHSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Maria Perez Regulatory Analyst l D XTO Energy, Inc. 200 N. Loraine, Suite 800 ` 1 Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, G Oil Pool, MGS C21A -23 Sundry Number: 311 -231 .;. # a "alb° , , I ' . 7 ?MI Dear Ms. Perez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Daniel T. Seamount, Jr. Chair DATED this day of July, 2011. Encl. II ! • Aro ENERGY RFC, s...E 20 July 20, 2011 Alaska Oil and Gas Conservation Commission s =, Vii: 'af '; r. Attn: John Norman, Commissioner ' ticri`froitio 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 Re: Form 10 -403, Request for Sundry approval Objective: Coil tbg re -perf HC -HZ and acid stimulation.. Middle Ground Shoal #C21A -23 MGS Field Cook Inlet, Alaska API 50 -733 - 10086 -01 XTO Energy Inc. hereby submits its Application for Sundry Approval for coil tbg re -perf and acid stimulation. Attached is the following information for your files: 1. Form 10 -403 Application for Sundry Approval. 2. Proposed job procedure. 3. Present wellbore schematic If you required additional information, please contact me at A/C 432 - 620 -4325. Sincerely, Maria L. Perez, Regulatory Analyst Copy to: Paul Figel, Engineering Manager 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 MIIIIM • 0 (II iL R. ECER IAICIK STATE OF ALASKA 1.0 , i i ii \ ! i : , ' I l i AL OIL AND GAS CONSERVATION COMMISSION V APPLICATION FOR SUNDRY APPROVALS Ai,Niya _. k °",,, +: ; r46. CliinfilISSiOri 20 AAC 25.280 w .., - 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ig Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy Inc. Development 0 Exploratory ❑ 191 -044 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 200 N. Loraine, Suite 800, Midland, Texas 79701 50 -733- 20129 -02 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No Ell Middle Ground Shoal C2�1A -23 9. Property Designation (Lease Number): 10. Field / Pool(s): i . / n >p y 1 ADL 18756 MGS -, t J , � c i ( 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): , Total Depth TVD (ft): • Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,290 9,719 12286 9717 None None Casing Length Size MD / TVD Burst Collapse Structural Conductor 370 24 370 370 Surface 1438 13 3/8 1438 1434 2730 1130 Intermediate 9320 9 5/8 9320 7747 6330 3810 Production 2684 7 11410 9204 7240 5410 Liner 1084 5 12290 9719 10140 10490 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11415 -12280 1 9204 -9709 2 7/8" r 6.5 #, L80 8R EUE - 11199 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7 "Baker SB -3 Perm 11145 SSSV 327 1 ' 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ - Exploratory ❑ Development El Service ❑ 14. Estimated Date for /1/19/ ?011 15. Well Status after proposed work: Commencing Operations: Oil El - Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 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 Paul Figel, Engr 432 - 620 -6743 Printed Name Maria Perez Title Regulatory Analyst Signature � Phone 432- 620 -4325 Date 7/20/2011 7/44/ ! 44/A COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5 ( ( -D31 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: (0 — 404. / APPROVED BY � ��� Approved by: COMMISSIONER THE COMMISSION Date: I " BONS 'vi 1;6%0,11 // ��� 1G1NAL Submit in Duplicate r ' Form 10 -403 Revised 1/2010 • S /TO PLF 6 -28 -11 ENERGY Present Completion yo KB: 35' MGS C21A -23 Water Depth: 73' MSL Cook Inlet, Alaska Tbg: 2 7/8" 6.5# L80 8R EUE @ 11,199' Leg 4, Conductor 27 *fol e API No.: 50- 733 - 20219 -02 Set: 7 -25 91 For Orig Well was C11 -23 ,,,p, S 0 idetracked: 5 -11 -91 2 -7/8" BXE SSSV (2.313" ID) @ 327' rt GLM #1 1839' 1828' 981 I 2 . , I tem MD TVD Ptro Conductor: 24" , Set @ 370'. __ GLM #3, 5454' ; 4742' 1000 116 GLM #4 6980'1 948 ' 12 �� GLM #6 , 9003' ' GLM #51 8124' E 5802 998 16 Surf Csg: 13 -3/8 54.5# K55 BTC. 998 16 Set @ 1,438'. Cmt'd w/ 520 sx. GLM #7 96671_18000' 1100 20 GLM #8 10396' 8506' 1099 1 20 GLM #9'° 11064' 8980' 1/4" Orifice IV /f ry e" //4 Intermediate: 9 5/8" L -80 LTC. off/74:°: Sliding @ 11,109', Anchor SealAss Sl Window Milled @ 9320'. y Surf - 4176' : 43.5# 11,144' Baker SB-3 Packer 11,145' 4176'-9320' : 47# , M illout Extension 11,149' TOC 18847'. Otis "XN" Ni le p p „ ( 2 2 05" ID) 11,187 ;"/"/","*:APIS ) WL Entry Guide 11,199' # Drilling Liner: 7" 26# L80 LTC. Set @ 11,410', TOL @ 8,726'. .... Cmt w/ 2,575 sk. 11111■ 1 ��� KoKy *- - ... :; ,/ r 10 Production Liner: 5" 18# N80 A4 Set @ 12,290'. TOL @ 11,206'. Cmt w/ 300 sx. Perf'd @ 4 spf: 577' Net (2,308 holes) HC-HD: 11,415'-11,460' , 0i2 HD-HE: 11,490' -11, 508' H E -H F: 11,564'-11,636' '00 : : - --- - HI-HK: 11, 734' -11, 764' VA HK -HN: 11,786'- 11,990' H N -H R:12, 008'- 12,108' Fish: GLV dropped 12 -31 -95 HN -HR:12,140'- 12,176' FILL: (None as of 10-17-10) HR -HZ: 12,208'- 12,280' PBTD: 12,286' MD . TD: 12,290' MD (9,719' TVD) . Tt' • ENERGY XTO Energy Inc. MGS C21A -23 West Flank Producer Cook Inlet, Alaska Re- Perforating & Acid Stim Procedure WELL DATA: SURFACE CASING: 13 -3/8 ", 54.5 #, K55, BTC. Set @ 1438'. Cmt w/ 520 sx. INTERMEDIATE CASING: 9 -5/8 ", 43.5 & 47 #, L80, LTC. Set @ 9320' (Window). DRILLING LINER: 7 ", 26 #, L80, LTC. Set @ 11,410'. TOL @ 8726'. Cmt w/ 2575 sx. PRODUCTION LINER: 5 ", 18 #, N80, FL4S. Set @ 12,290'. TOL @ 11,206'. Cmt / 300 sx. PBTD: 12,286' PERFORATIONS: HC -HD: 11,415 — 11,460' HD -HE: 11,490 — 11,508' HE -HF: 11,564 — 11,636' Shot 4 spf = 2,308 perfs HI -HK: 11,734 — 11,764' HK -HN: 11,786 — 11,990' HN -HR: 12,008 — 12,108' & 12,140 — 12,176' HR -HZ: 12,208 — 12,280' NET PAY: 577' TUBING: 2 -7/8 ", 6.5 #, L80, 8rd EUE @ 11,199'. PACKER: 7" Baker "SB -3" permanent pkr @ 11,145'. Set 7- 25 -91. BHST: 170 Deg F BHP: 3500 psi SMALLEST ID: 2 -7/8" XN Nipple: 2.205" ID @ 11,187'. Will be milled to 2.30 ". MAX DEVIATION: 55 degrees @ TD 12,290' PRESENT STATUS: Prod @ 46 BOPD, 19 BWPD as of 6- 22 -11. OBJECTIVE: Coil Tbg Re- Perforate HC —HZ and acid stimulate perfs. NOTES: • AFE # 1104410 • Barney to pull the orifice valve @ 11,064' 2 -3 days prior to RU the CTU. Use mud pumps to circ the well with FIW to kill the well. • The XN Nipple @ 11,187' will be milled out to 2.30 ". • Heat FIW to ±100 ° F 7 -18 -11 • • XTO Energy Inc. 2 MGS C21A -23 COOK INLET, ALASKA Materials Required: • 10,000 gal (238 bbl)10% HCL DAD Acid (25% xylene) • 20 bbl Gel Pill (1/2 gal / bbl Liquid HEC -10 + 1 gal Greencide) (Provided by MI) • 750 bbl 3% KCL FIW Water ➢ 7,500 lbs Powdered KCL (1000 lbs KCL /100 bbl FIW for 3 %) (Provided by MI) ➢ 75 gal B145 Friction Reducer (SLB) • N2 bottles to purge reel after job or N2 unit • 100 gal Nalco EC6079A Scale Inhibitor Equipment Required: • 1.75" CTU • Filter Skid (3 -5 micron) • 250 bbl PTS Flowback Tank ➢ Mud Pump to be tied into tank to pump load to C44 -14RD Disposal Well ➢ Install 2" line from tank top to production header for gas lift @ EOJ • Return line w/ choke manifold to 250 bbl Surge Tank & to Production Facilities ➢ Manifold to contain a sample catcher to monitor fluids pH • Baker 1-11/16" mud motor w/ 2.30" bit • Expro memory log • ±44 ea 2.0" Razor HMX guns loaded 6 spf @ 60 Degrees (288' Blank Pipe) DAD Acid System to contain these additives: • 10% HCL • 250 gpt Xylene • 15 gpt U74 Dispersing Agent • 5 gpt A261 Corrosion Inhibitor • 8 ppt A153 Corrosion Inhibitor Aid • 20 ppt L58 Iron Reducing Agent • 5 gpt W60 Anti - sludge • 5 gpt W54 Non - Emulsifier • 2 gpt F103 Surfactant 7 -18 -11 • • • XTO Energy Inc. 3 MGS C21A -23 COOK INLET, ALASKA PROCEDURE: 1. Well should be dead. MIRU Schlumberger 1.75" Coil Tbg Unit. RU a filter skid between the mud pits & HP triplex. Install press gauges on the CT, CT Annulus, & 2 -7/8" prod tbg annulus. Make up Baker 1- 11/16" mud motor w/ 2.30" mill. Contact the AOGCC 24 hrs prior to BOP test. Press test all lines & BOP's to 5,000i. Max Press = 4;000 psi. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.205" XN- Nipple @ 11,187'. 2. Conduct a pre job safety meeting with all SLB, Expro & XTO platform personnel. MILL RUN: 3. Open the CT annulus. RIH w/ motor & mill @ 100 fpm while circ 0.5 BPM slick 3% KCL FIW to XN @ 11,187'. Flag the coil tbg. Mill out nipple to 2.30 ". 4. Cont downhole to PBTD @ 12,286' @ 25 fpm & circ 0.5 BPM slick 3% KCL. POOH & LD motor /mill. CLEANOUT HOLE & MEMORY LOG RUN: 5. MU Expro Memory GR/CCL tool w/ circ port. 6. Open the CT annulus. RIH @ 80 fpm while pumping slick 3% KCL FIW @ 0.25 BPM from surface to 11,100'. 7. Slow coil rate to 10 -20 fpm @ 11,000 — 11,200' as BHA passes through the sliding sleeve & packer assembly. Cont RIH @ 50 fpm. Lightly tag, p'@ 12,286'. Flag the coil tbg. 8. PUH @ 60 fpm while logging from 12,286 — 11,300' & cont to pump slick 3% KCL @ 0.25 BPM. 9. POOH @ 100 fpm. 10. SI the BOP's & RD Memory Log Sub. RD the injector head. Download the GR/CCL data. Correlate to the Western Atlas LLG 7 -7 -91. (No CCL log avail.) Cont to monitor well for any press. TCP PERFORATING: NOTE: Verify that a 7/16" steel ball to fire the guns will drift through the BHA before making it up to the coiled tubing. 11. Hold a pre job safety before picking up the perforating guns. Designate the essential personnel allowed on the rig floor while making up the guns. The well must be dead before deploying or retrieving the gun string. 7 -18 -11 • • XTO Energy Inc. 4 MGS C21A -23 COOK INLET, ALASKA 12. Based upon tagging bottom in Step #7, gun length may need to be shortened. Open the BOP's & MU the ±44 ea 2.0" Razor HMX TCP guns with slips & safety dog collar. Guns to be loaded @ 6 jspf @ 60 degree phasing. Have deployment bars & TIW valve ready and available to deploy if reqd. RU hydraulic ball firing head to coil tbg. RU the injector head. 13. Lower the guns below the BOP's. Close the pipe rams & annular preventer on the coil tbg above the firing head. Perform a 5,000 psi press test on the lubricator above the annular preventer. 14. RIH with the TCP guns @ 80 fpm from surface to 11,000'. 15. Slow to 10 -20 fpm while the guns pass the sliding sleeve /packer section from 11,000 — 11,200'. 16. Correlate depths to fire guns @ 11,415 — 12,280'. Match up the CT flag from previous run. Top BTM Length Perfs 11415 11460 45 Blank 11460 11490 30 Perfs 11490 11508 18 Blank 11508 11564 56 Perfs 11564 11636 72 Blank 11636 11734 98 Perfs 11734 11764 30 Blank 11764 11786 22 Perfs 11786 11990 204 Blank 11990 12008 18 Perfs 12008 12108 100 Blank 12108 12140 32 Perfs 12140 12176 36 Blank 12176 12208 32 Perfs 12208 12280 72 Net Pay 577 Gross Pay 865 17. Drop the 7/16" steel ball and pump ball down to the seat. Pressure up to ±3000 psi to fire guns. NOTE: IF GUNS MUST BE PULLED & WERE NOT FIRED AFTER DROPPING THE BALL, THERE IS TO BE NO PUMPING DOWN THE COIL TBG. PLACE LOCK -OUT ON THE PUMP. 18. Immediately after the guns fire, POOH @ 30 fpm while passing through the sliding sleeve /pkr section. Once cleared, POOH 80 fpm. 19. Monitor the WH press white POOH. If necessary, pump weighted FIW to kill the well•prior to pulling the guns. 20. Once the guns make it to surface, SD & conduct a safety meeting to address gun handling & possible well pressure issues. Conduct a no -flow test. Fill hole after every 10 guns are POOH. Only essential personnel need to be on the rig floor when the guns are being LD. 7 -18 -11 • • • XTO Energy Inc. 5 MGS C21A -23 COOK INLET, ALASKA 21. RD the injector head. 22. Break out the guns, noting if any shots did not fire. 23. RU Inj head & press test. ACID SPOT & SOAK: 24. MU wash tool. Open the CT annu}us. RIH @ 80 fpm while pumping @ 0.25 BPM slick 3% FIW to @ 12,280'. Lay 675 gal (16 bbl) 10% DAD acid from 12,280 - 11,400' while PUH using slick 3% FIW to displace @ 42 fpm & 0.75 BPM. PU CT to 11,300' & SD. Let acid soak for 30 min. 25. RIH & tag up @ 12,286' while circ out acid with slick 3% FIW @ 1.5 BPM. At 12,286', circ hole clean w/ 10 bbl Gel Pill followed with 80 bbl slick 3% FIW. Do NOT mix anv friction reducer to FIW beyond this step. ACID INJECTION JOB: 26. SI the CT annulus. Inject 9250 gal (220 bbl) 10% DAD acid into the perf's while making 4 passes across the interval from 12,280 — 11,400' while pumping @ 0.7 BPM & 11 fpm. Finish pumping all acid @ 12,280'. 27. Mix 100 gal Nalco EC6079A Scale Inhibitor in 200 bbl 3% KCL FIW (no friction reducer). Over - displace acid by injecting 200 bbl 3% FIW + Scale Inhibitor @ 0.7 BPM. Make 3 passes from 12,280 — 11,400' @ 10 fpm. 28. Open CT annulus. POOH with coil tbg @ 100 fpm. Close the swab valve. Bleed off press. RD Coil Tbg Unit. 29. Slowly start up gas lift taking returns to the PTS tank. Cont to flow into PTS tank until pH is neutral (7). Switch returns into production header & start testing well. Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. Paul Figel Engineering Manager 7 -18 -11 Safety Valve & Well Pressures Test Report Reviewed Bi: ~ ` Y.1. Supr f = Z ~ ~G Comm Pad: MGS_XTO_C_PLATF InspDt: 2/22/2008 °~Inspected by John Crisp Field Name MIDDLE GROUND SHOAL Operator XTO ENERGY INC Interval InspNo svsJCi~080225134306 Operator Rep Barney Phillips Related lnsp: Reason 90-Day `~ Sre: Inspector j Well Data Pilots SSV SSSV Shutln Dt 6i'ell Type ~ Well Pressures ~ Gas Lift Wacver Comments ~- - ---- - ~ ~ --1- ~---~ Well Permit Separ Set UP Test Test Pest Date SI OiI,WAG,GINJ, Inner Outer Tubing Number Number PSl PSl Trip Code Cude Code GASCYCt F st Pst Pci uc~ V.,c/N,. V..../ti_ ~ C12 23 C13 23 _. -j C13A 23 1900200 1880990 ----- - ~ 1901060 68 68 -- 68 37 37 37 T 37 _.- - 0 P ~ P -- P P -- P P P --- P - -- --- t-01L 1-OIL -O1L - -- -- - - - -- - - _ l ------ --- -- --- - - i - - -- -- - ---- - -- ---- - --- - ----- __ - - ---- - C21 23 ; __ C21 26 1890870 _ _ __ __ 1890040 i 68 - ! 68 ~ 0 .- ' -- 0 i -- - P --- P ---- P -- ---- - 1-O1L - 1-OIL --- - ~ ~ -- -- - - --- t SSSV ---- -- ---~' out for W/L work r - - -~- - - ---~ C21A 23 •. --- - ~ C22 26RD ' 1910440 ~ - -a 176065 ' 68 -- 0 j -_ ~ P P - -- ~ - 1-0IL ~ +- -- -- - ~----- - -- -- - --- -j - C22A-26LN C31-26RD C32-23LW ------ f 0 2041820 2041400 2020340 ------- 68 68 68 68 ~ -- 0 j 0 _ ~0 _ _-._. 0 i -- P _ - P V ~ P - P P P p -- ~ -- t -OIL 1-0IL l-OIL - 1-0[L --- ~ --- -r---- - y i - -`-"_ -- - _ --- ~ --- - ~ - - - -...-------- --- -~ ---- C42-23 -C43-14 1780240 1881320 1 68 ~ 68 I 0 ~ ~ 0 ~ P P P P --- t-0IL 1-OIL ~ - --+--- - -. --- - - - - - ----- ---------- ---I r i • Comments Performance Pilot numbers listed on wells C12-23 & C13-23 are for the pilots on the separators. Individual wells are - --- ----- -- not equiped with pilots on this platform. ;/ Wells Components Failures Failure Rate 12 25 0 _ ~ ~~~ BAR ~. 20~F~ • Tuesday, February 26, 2008 ., e e ;[19 RECE\VEO JUN 0 9 'lOUG XTOEnergylnc. ,200 North Loraine G Cons Cl)fTI'riss\9t\\te 800 A\aska Oi\ & as' Midland, Texas 79701 Anchorage 432-682-8873 432-687-0862 (Fax) June 5, 2006 \q\; 04"-1 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 ,,-!(~ .i i\'>i'\\~~ f ~~v-:\.",ì\;., "W;.h'" RE: Sundry Well Operations Report: Well #C21A-23 - Coil Tubing Stimulation Dear Mr. Norman, XTO Energy, Inc. hereby submits its Sundry Operations Report (Form 10-404) for the coil tubing stimulation performed on the producing well #C21A-23. This well is located on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. Please find attached the following information for your files: 1. Form 10-404 Sundry Well Operations Report 2. Daily Report of Operations 3. Present Wellbore Schematic If you have any questions or require additional information, please contact me at (432) 620-6742. Sincerely, 911~ Jeff Gasch Production Engineer Cc: Paul Figel Scott Griffith Tim Smith 3. Address: 200 N. Loraine, Ste 800, Midland, Texas 79701 STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM.ION JUN 0 9 tOO;' REPORT OF SUNDRY WELL OPERATION~f k 0 0 as a if & Gas Cons. Commis Repair Well Plug Perforations Stimulate'¡ , Other C raae Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 4. Well Class Before Work: 5. Permit to Drill Number: Development 0 ExploratoryD 191-044 ' Stratigraphic 0 Service 0 6. API Number: 50-733-20129-02 J-<t:celVED 1. Operations Abandon Performed: Alter Casing 0 Change Approved Program 0 2. Operator XTO Energy Inc. Name: 7. KB Elevation (ft): 35' 8. Property Designation: ADL-18756 . 11. Present Well Condition Summary: 9. Well Name and Number: C21A-23 10. Field/Pool(s): Middle Ground Shoal € F 9 - 0,1 ~ 5 Z.lf/1t( {¿d3·DIP Total Depth measured 12290' feet true vertical 9719' feet Effective Depth measured 12286' feet true vertical 9717' feet Casing Length Size MD Structural Conductor 370' 24" 370' Surface 1438' 13-3/8" 1438' Intermediate 9320' 9-5/8" 9320 Production 2684' 7" 1141 0' Liner 1084' 5" 12290' Perforation depth: Measured depth: 11415' - 12280' Plugs (measured) None Junk (measured) None TVD Burst Collapse 370' 1434' 7747' 9204' 9719' 2730 6330 7240 10140 1130 3810 5410 10490 True Vertical depth: 9204' - 9709' Tubing: (size, grade, and measured depth) 2-7/8" L-80 11199' Packers and SSSV (type and measured depth) 7" Baker SB-3 Perm pkr @ 11145' & Otis XXO Ball SSSV @ 327' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11415' - 12280' RBDMS 8Fl JUN 1 4 2006 Treatment descriptions including volumes used and final pressure: Acidized w/ 12,500 gals 80/20 10% HCUXylene through coil tubing. 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 34 33 . Final inj pressure - 4800 psi @ 0.5 BPM' Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 39 5 440 57 16 415 Tubing Pressure 70 70 15. Well Class after work: Exploratory 0 X 16. Well Status after work: Well Schematic Oil 0' Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Development 0 Service 0 WAG 0 GINJ 0 WINJ 0 WDSPL Sundry Number or N/A if C.O. Exempt: 305-116 o Contact Jeff Gasch Printed Name Jeff Gasch Title Production Engineer Signature ç¡!k.L Phone 432-620-6742 Date 6/5/2006 Form 10-404 Revised 04/2006 ~h~~ 4,¡;;:¡;;i9i~.~n;dc Page 1 of 2 XTO Energy - Midland District W orkover Report . M.and Well W orkover Re.rt IIMIDDLE GROUND SHOAL C Objective: Coil Tbg Acid Stimulation First Report: AFE: 4/25/06 II II Well # 21A-23 II 04/25/2006 504336 4/26/06 Begin prep work for coil tbg job. Off load boat wi BJ equip. Con't RU CT equip. Off load boat wi chemicals, mud products, & 500 bbl frac tank. Cleaned pits - a lot of rust. Blend Acid. RU riser, BOPE, injector head & stabbed coil. 4/27/06 Mixed up 3% KCL wtr. RU flow-back tank. MU CT BRA. Stabbed inj head. RU for BOP test. Press test coil, BOP & riser 25015000 psi. PT lines to 250/6000 psi. Fin RU flow-back tank. Offload & RU filter skid. PJSM. OWU. RIH wi Vortech wash nozzle pmpg slick 3% KCL wtr @ 1 BPM @ 2100 psi 2100 psi at 80 fpm. Slowed CT rate to 20 fpm while washing perfs 11,415 -12,255'. Had to SD to CO in-line filter. Ran out cartridges on filter skid (4 changes). Tagged 31'high @ 12,255'. Could not wash down. PUR laying 16.5 bbllO% HCL from 12,255 - 11,375'. Displ wi 3% KCL.SD for 30 min for acid soak. RIH circ out acid wi 50 bb13% KCL. Tagged up @ 12,255'. Cont circ 15 bb13% KCL @ 1 BPM @ 4500 psi. Pmpd 8 bbl gel sweep. Press cont to incr to 4800 psi. SD. Pulled in-line filter. Filter plugged wi LCM frl pits. Cleaned & replaced. Circ 75 bbls 3% KCL @ 1.25 BPM @ 3800 psi. Getting thick emulsion rtns. Cln rtns. PUH @ 15 fpm washed perfs wi 58 bbl HCL @ 1 BPM @ 4,000 psi. SD @ 4900 psi @ 0.6 BPM. CO filter. Con't PUH & acid washing @ 0.7 BPM @ 4,400 psi. Start flush. (Will circ out acid & then POOH to change out BHA filter for acid sqz.) 4/28/06 Pmpd 10 bbl gel sweep. Pulled and cleaned in-line filter. POOH chasing sweep wi 3% KCL. Change out BHA wI tapered wash nozzle. Did not run downhole filter on new BHA, BHA filter was plugged wi sand, LCM, flo-visc. RIH wi wash nozzle and tag at 11,180'. (2-7/8" XN Nipple @ 11,187) Make multiple attempts to work past. Could not wash down. Spot 6 bbl acid @ 11,180' and let soak. Attempt to work past 11,180' with no success. Pits were emptied and cleaned thoroughly. Remixed 3% KCL. Surge well attempting to work past 11,180' with no success. POOH chasing acid wi 3% KCL. MU CT BHA wi 2-1/8" tapered mill, PDM and circulation sub. RIH @ 60 fpm pumping 3% KCL @ 0.4 BPM & 750 psi. Tagged @ 12,260'. Drop ball and open circulation sub. (Will start acid once circ sub is open). 4/29/06 Spot acid to end of CT. Close in backside & begin acid injection @ 0.9 BPM, 3,000 psi on WH & 5,000 psi pump press. In-line filter cleaned after pumping 62 bbl acid. Plugged wlfilm from acid, no solids. Pmpd 60 bbls acid @ 0.3 BPM & 3400 psi on WHo Acid system was very viscous causing large pressure drop in CT. Pmpd 67 bbl 3% KCL to test inj rate wi water. Ended @ 0.6 BPM & 5000 psi on CT SD to investigate acid viscosity. Discuss situation wi BJ rep & chemical lab. Acid appears to be foamed. Add 90 gals diesel & 5 gals FRW-14 friction reducer to remaining 230 bbl acid. Roll acid tanks to mix. Could not mix thoroughly. Send samples of acid system & FIW to BJ lab. Order out new acid system (10,000 gal 10% One Shot Plus - 80% HCL 120% Xylene). Pmpd 100 bbls 3% KCL @ 0.7 BPM & 4,150 psi. PUR to 11,099' & SI. Pmpd 100 bbl bad acid dwn disposal well. (Continue pumping bad acid down disposal well and clean tank in preparation for new acid system.) 4/30/06 Mixed FIW to thin bad acid & pump to disposal well. Cleaned acid tank in preparation for new acid system. Blend 10,000 gal 10% One Shot Plus acid (80% HCL I 20% Xylene). 5/1/06 Finished blending 10,000 gals 10% One Shot Plus acid. Spot acid to end of CT. Squeezed 230 bbls acid @ 5,000 psi & 0.4 BPM while making passes across perfs @ 10 fpm. Flush CT wi 100 bbl 3% KCL @ 4,800 psi & 0.5 BPM while making 2 passes across perfs @ 10 fpm. SD pmp @ 11,400'. ISIP = 4700 psi. Cont http://dor/repCworkover.asp 6/5/2006 XTO Energy - Midland District W orkover Report . . POOH. 5" = 3840, 10" = . psi, 15" = 2400. RD CT equipment. . for flow back. Page 2 of 2 5/2/06 Cont RD CTD. RU flow-back tank. Start flowing @ 12:30 pm. Back load equipment to go to onshore. Prep equipment to go to platform A. Only rcd 3 bbl in 6 hrs. (Not putting enough lift gas to well.) 5/3/06 Changed orifice. Incr Header press to 950 psi & lift gas rate. Well started unloaded. Unloaded 30 bbl in 1 hr. Csg Press @ 600 psi lifting on orifice. Recovering acid load @ 3-4 BPH @ 0600 hrs flowed back 110 bbls total. 5/4/06 10% Oil cut @ 10:00. Acid still hot. 15% oil cut wi 1 % fines @ 17:00. Acid still hot. 24 hr load recovered @ end of report @ 172 bbl. 5/5/06 Monitor flow-back tank and send returns to disposal. Clean mud pits. Recovered 242 bbls total. 5/6/06 Monitor flow-back tank and send returns to disposal. Recovered 294 bbls total, 15% oil, ph - 3. Flowing 2.5 - 3 bph. 5/7/06 Monitor flow-back tank and send returns to disposal. Recovered 340 bbls total, ph - 2.5 - 3. 5/8/06 Monitor flow-back tank and send returns to disposal. Recovered 342 bbls total. Turn over well to production. RD flow-back tank. 5/17/06 12 hr test - 17 bopd I 18 bwpd I 27 mcfpd. 5/19/06 12 hr test - 22 bopd I 10 bwpd I 12 mcfpd. Rig up wireline and pressure test lubricator. RIH with 2.44" scratcher to 292' WLM. Made several passes through safety valve nipple. POOH. RIH with 2.313" Otis BXE ball valve to 292' WLM. Locate and set. POOH. Perform state test on SV. Test good. RD. http://dor/repCworkover.asp 6/5/2006 .. ~TO ~~RGY MGS C21A-23 Cook Inlet, Alaska Leg 4, Conductor 27 API No.: 50-733-20219-02 Orig Well was C11-23 Sidetracked: 5-11-91 Conductor: 24" , Set @ 370'. Surf Csg: 13-3/8" 54.5# K55 BTC. Set @ 1,438'. Cmt'd wI 520 sx. Intermediate: 9-5/8" L-80 LTC. Window Milled @ 9320'. Surf - 4176' : 43.5# 4176'-9320' : 47# TOC ±8847'. Drilling Liner: 7" 26# L80 LTC. Set @ 11,410', TOL @ 8,726'. Cmt wI 2,575 sk. Production Liner: 5" 18# N80 FL4S. Set @ 12,290'. TOL @ 11,206'. Cmt wI 300 sx. e Present ComDletion Fish: GLV dropped 12-31-95 FILL: (None as of 3-12-04) PBTD: 12,286' MD TD: 12,290' MD (9,719' TVD) e PLF 3-31-05 KB: 35' Water Depth: 73' MSL Tbg: 27/8"6.5# L80 8R EUE @ 11,199' Set: 7-25-91 i Item ~~~ . .. . GLM #1 G~~J~2 GLM #3 GLM #4 GLM #5, . GLM #6 GLM #7 2-7/8" SSSV (2.313" ID) @ 327' r-='-~'~"'~"'."'" .'. .......,.. .-" ...... ,.....-. .,...-. i Oti~ :?5()" SIi~l~~!L~le~\ß nchor Seal Assy SB-3 Packer tension ".~IpËI~..~2.205".,lb) L Entry Guide 09' ~1,144' ,11,145' . 11, 14~f ....' ...J 11 , 187' 11 19~fi ..~.......J Perfd @ 4 spf: 577' Net (2,308 holes) HC-HD: 11,415'-11,460' HD-HE: 11,490'-11,508' HE-HF: 11,564'-11,636' HI-HK: 11,734'-11,764' HK-HN: 11,786'-11,990' HN-HR: 12,008'-12,108' HN-HR: 12,140'-12,176' HR-HZ: 12,208'-12,280' Re: Sundries #305-142 for A43-11LS2 & #305-116 for C21A-23 e e Hi Paul, The sundries are still good. Unlike permits to drill, they don't expire in 2 years although in the next regulation redo I think a 2 year limit will be placed on them. Good of you to check. I think that regardless of the sundry still being "good", it is important to recheck what was planned versus new or changed well conditions. I will place a copy of this message in the well files. When you get the new procedure/fluid/schedule determined for A34-11LS2 just send it in by email. Call or message with any questions. Tom Maunder, PE AOGCC ?_9.:~.L~J:-s~l£!1~!:genE;E3Y:S:£.I!:l wrot e , On 4/13 / 2006 5: 54 AM: Tom, These are 2 wells that I had planned doing coil tbg stimulations last summer but got put on hold. I now have the green light. The Sundries were approved in June '05 for the A34-11LS2 & May '05 for the C21A-23. Is there a time that a granted Sundry expires? There are no changes to the C21A-23. However, there will be some changes to the stimulation fluid & pump schedule on the A34-11LS2. I had Hemlock cores samples sent in for testing where I damaged the core w/ oil based mud & had BJ try to find the best antidote to regain the core perm. The lab report was supposed to be in yesterday but still waiting. The work I scheduled is to begin on Monday April 24th. When I get the core lab test report on the A34-111S2, I'll e-mail to replace the Procedure dated 6-4-05. Let me know if the Sundries are good to go or if they are expired. Thanks, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 . .(;.~., ~·I<\ít.--~~ . """ '. ..",..-.- :;J ,."'. 1\;,"' .'-''' é¡ t;), c 1 of 1 4/13/20068:25 AM ') ) (f.,.l'.U....'.I... "0..·1,.;11 t\~, ~: 'n:·\~ ¡ II ;,,,,1.) u S, '''?::¡ï?,,' rl ;' L :1; : v-oJ : ¡i ¡I L ì."J :>_"':3 ',[' -;,~,.,\ : J :1 : ; HI! I,U iI,i J\,,-.J FRANK H. MURKOWSKI, GOVERNOR AI¡ASH& OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Figel Engineering Manager XTO Energy Inc. 200 North Loraine, Suite 800 Midland, Texas 79701 tqt·~ot.þlf Re: Middle Ground Shoal C21A-23 Sundry Number: 305-116 SCANNED MA~( 11 2005 Dear Mr. Figel: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the rd day following the date of this letter, or the next working day if the 23rd day fall on a holiday or weekend. A person may not appeal a Commission decision to Su Zior ourt unless rehearing has been requested. =z . c el ' I ~ / o~ ChaIrman DATED this5day of May, 2005 Enc!. ) ) I,t . ;(TO ~~RGY XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 7970 I 432-682-8873 432-687-0862 (Fax) May 3, 2005 RECEIVED MAY 0 4 2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Ahu;kl Oil & Gas Cons. CQmmisli~m Anchorage RE: Request for Sundry Approval to acid stimulate well C21A-23. V~ - oLf'lt Dear Mr. Norman: XTO Energy, Inc. hereby submits its Application for Sundry Approval to acid stimulate well C21A- 23 on Platform C, in the Middle Ground Shoal Field of Cook Inlet. The treatment will be done using coil tubing. The well is an oil producer in the West Flank Hemlock reservoir. Please find attached the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Job Procedure 3. Present Wellbore Schematic Please contact me with any questions @ 432-620-6743. S incerel y, 9~ ¿/. ~ Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith o R \ G \~~ /\ L fftS S&.s' .; \ STATE OF ALASKA C ) 5"-(" "'0 'j ALA~. .Á OIL AND GAS CONSERVATION COMrvllvSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Abandon U Alter casing D Change approved program D 2. Operator Name: XTO Energy Inc. 3. Address: 1. Type of Req uest: 200 N. Loraine, Ste 800, Midland, Texas 79701 7. KB Elevation (ft): 35' 8. Property Designation: ADL-18756 11. Total Depth MD (ft): 12290' Casing S tru ctu ra I Conductor 370' Surface 1438' Intermediate 9320' Production 2684' Liner 1084' Perforation Depth MD (ft): 11415' Packers and SSSV Type: Total Depth TVD (ft): 9719' Length RECEIVED J- MAY04Z005 5~ Perforate U AlaskilJQij~èi~ ~Ù1aM);~~6§~ÔI1 Stimulate 0 Time Extension ~chorage Other D Re-enter Suspended Well D 5. Permit to Drill Number: Suspend U Repair well D Pull Tubing D Development Stratigraphic o D Exploratory D D "Q~ ~4· \~!:\':~~ 6. API Number: ,..O~ 50-733-~-02 ~ JO \ ð'\ -0 :).. Service 9. Well Name and Number: C21A-23 10. Field/Pools(s): Middle Ground Shoal PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 12286' 9717' Size MD TVD Plugs (measured): None Junk (measured): None Burst Collapse 24" 370' 1438' 9320' 1141 0' 12290' Tubing Size: 2-7/8" 370' 1434' 7747' 9204' 9719' 2730' 6330' 7240' 10140' Perforation Depth TVD (ft): 9204' Tubing Grade: L80 Packers and SSSV MD (ft): 1130' 3810' 5410' 10490' Tubing MD (ft): 11199' Pkr @ 11,145' & SSSV @ 327' 13-3/8" 9-518" 7" 5" Baker 7" SB-3 Perm pkr/Otis XXO Ball valve 12. Attachments: Description Summary of Proposal L.:::J Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name() Paul Figel Title Engineer Manager Signature <¡/ 4.-t ~. ~p Phone 432-620-6743 Date ð COMMISSION USE ONLY 5/16/05 Date: 13. Well Class after proposed work: Exploratory D Development 0 Service D 15. Well Status after proposed work: Oil 0 Gas D Plugged D Abandoned D WAG D GINJ D WINJ D WDSPL D Paul Figel 5/3/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .3D'S- /I~ Plug Integrity D Other: BOP Test ~ '----- Form 10-403 Revised 12/2003 Mechanical Integrity Test D Location Clearance D RBDMS BFL MAYO 9 2005 (u) ID ¡~ ('"'\ . \ ¡ \ ~~l ¡\J A L BY ORDER OF COMMISSIONER THE COMMISSION Date: ¢~{ Submit in Duplicate INSTRUCTIONS ON REVERSE ·~TO ~kRGY '.. , ! ) XTO ENERGY INC. J\IGS C21A-23 WEST FLANK PRODUCER COOK INLET, ALASKA COIL TBG ACID STIMULATION PROCEDURE WELL DATA: SURFACE CASING: 13-3/8",54.5#, K55, BTC. Set @ 1,438'. Cmt wi 520 sx. INTERMEDIATE CASING: 9-5/8",43.5 & 47#, L80, LTC. Set @ 9,320' (Window). DRILLING LINER: PRODUCTION LINER: PBTD: PERFORATIONS: NET PAY: TUBING: PACKER: BHST: BHP: SMALLEST ill: l\IAX DEVIATION: PRESENT STATUS: 7",26#, L80, LTC. Set @ 11,410'. TOL @ 8,726'. Cmt wi 2,575 sx. 5",18#, N80, FL4S. Set @ 12,290'. TOL @ 11,206'. Cmt I 300 sx. 12,286' HC-HD: 11,415 - 11,460' HD-HE: 11,490 - 11,508' HE-HF: 11,564 - 11,636' Shot 4 spf = 2,308 perfs HI-HK: 11,734 - 11,764' HK-HN: 11,786 -11,990' HN-HR: 12,008 - 12,108' & 12,140 - 12,176' . HR-HZ: 12,208 - 12,280' 577' 2-7/8",6.5#, L80, 8rd EUE @ 11,199'. 7" Baker "SB-3" permanent pkr @ 11,145'. Set 7-25-91. 160 Deg F 3,200 psi 2-7/8" XN Nipple: 2.205" ID @ 11,187'. 55 degrees @ TD 12,290' Prod @ 58 BOPD, nil HWPD, & 21 MCF as of 3-24-05. OBJECTIVE: Acidize well using Coil tbg. NOTES: · Acid to be tested wi oil sample that contains 500 ppm ferric iron (Fe3). · No acid is to be pumped into the production header system. A 250 bbl flowback PTS tank will be used to handle all acid returns. · It is anticipated to immediately follow this wen with the coil tbg stimulation for C32-23LvV. Procedure 4-1-05 r:; ) X}:'O Energy Inc. . MGS C21A-23 Cook Inlet, Alaska 2 Materials Required: · 18,000 gal (429 bbl) 10% One-Shot Plus Acid (25% xylene:75% - 100/0 HCL) · 40 bbl Gel Pill (3#/bbl Flo- Visc + 5 gall! 00 bbl Greencide provided by MI) · 700 bbl3% KCL FIW Water (Friction Reducer Supplied by BJ) ~ 1 gal/lOa gal FRW-14 BJ Friction Reducer ~ 7,000 lbs KCL (1,000 lbs 1100 bbl FIW for 3%) Supplied by MI · N2 bottles to purge reel after job · 4,000 lbs Soda Ash (Supplied by MI) Equipment Required: · BJ 1 %" CTU: Install press gauges on CT, CT annulus and 2-7/8" tbg annulus. · 1 ea HP Triplex Pump · Filter Skid (8 micron) MI · 500 bbl Plastic Lined Acid Tank (Supplied by R&K) · Vortech Wash Tool · 250 bbl Plowback Tank ~ Mud Pump to be tied into tank to pump load to C44-14RD Disposal Well ~ Install 2" vent hose on top of tank to vent overboard · Return line wi choke manifold to 250 bbl Surge Tank & to Production Header );.> Manifold to contain a sample catcher to monitor fluids pH );.> Send only "clean" returns to the Production Header ~ Send live acid and or fluids containing scale or solids to Plowback Tank. · Have a H2S monitor @ the Flowback Tank. Acid System to contain these additives (Cone. dependent on acid / oil compatibility test): · 10% HCL (Acid to·be titrated on location.) · 250 gpt Xylene · 1 gpt PRW-14 Friction Reducer · 5 gpt CI-27 Corrosion Inhibitor · 7 ppt F200 Iron' Reducing Agent" · 30 ppt P300 Iron Chelating Agent · One Shot Plus additive (3 :2) Procedure 4-1-05 XTO Energy Inc. MGS C21A-23 Cook Inlet, Alaska ), :, I,·"") } 3 PROCEDURE: 1. SD gas lift. RU Slickline & lubricator. RIH wi 2.4" scratcher to SSSV @ 327'. POOH. RIH w/ pulling tool & POOH w/2313" BXE ball valve. 2. RIH w/ 2.4" scratcher past EOT @ 11,199'. Con't DH & tag for fill. POOH & RD WL. 3. MIRU BJ 1.75" Coil tbg unit, riser, BOP's & Injector head. Contact AOGCC 24 hrs prior to BOP test. Press test BOP's to 5,000 psi. Test treating lines to 6,000 psi. Max press is 5,000 psi. MU Vortech wash nozzle on EOT. CTU operator to ensure all tools to be calìpered before RIH. Smallest ID = 2.205" @ XN Nipple @ 11,187'. 4. Hold safety meeting with all service & production personnel about the procedure, corrosive chemicals, and possible H2S exposure. 5. Open WH for circ. RIH \v/ coil tbg @ 80 fpm down the tbgwhile pumping @ 1 BPM slick 30/0 KCL FIW. 6. Wash the perforated interval 11,415' -12,280' @ 20 fpm & 1.5 BPM slick 30/0 KCL. Tag PBTD @ 12,286' . ACID SPOT & SOAK: 7. Lay 16.5 bbl of acid/xylene from 12,286' to 11,375' while pulling up hole with coil tbg. Displace acid out of coil with 30/0 KCL. Pull up to 11,300'. SD & let acid soak for 30 min. Have 3,700 lbs soda ash in PTS flowback tank. 8. Keeping the CTannulus open, RIH @ 40 fpm to 12,286' while circ slick 30/0 KCL to surface @ 1.5 BPM. Circ hole clean w/ 10 bbl Flo- Visc pill to surface followed with 100 bbl slick 3% KCL. Send all returns to the Flowback Tan1e Pump load from PTS tank into disposal well C44-14RD. ACID WASH PERFS: _ 9. Pump 58 bbl acid/xylene @ 1 BPM while washing the perfs from 12,286 - 11,400' while making 1 pass @ 15 fpm. 10. RIH @ 40 fpm to 12,286' while circ slick 30/0 KCL to surface @ 1.5 BPM. Circ hole clean w/ 10 bbl Flo-Visc pill to surface followed with 100 bbl slick 3% KCL. Do NOT mix any friction reducer (FRW-14) to the 3% KCL FIW beyond this step. A,CID INJECTION JOB: 11. SI in the WHo Inj 345bbl acid/xylene while making 4 passes across the perfs from 12,286 - 11,400' while pumping @ 0.5 BPM and moving the coil tbg @ 5 ft/min. Maximize pump rate under 5,000 psi & adjust coil speed to complete the 4 passes. 12. Finish pumping all acid @ 12,286'. Over-displace acid by injecting 100 bbI3% KCL (NO FRICTION REDUCER) @ ±0.5 BPM. Make 2 passes from 12,286 -11,400' @ 9 fpm. Procedure 4-1-05 XTO Energy Inc. , MGS C21A-23 Cook Inlet, Alaska 'f'''¡ f' 4 13. Open the WHo POOH wi coil tbg @ 100 fpm. Close the swab valve. 14. The plan is to move the coil tbg unit over to C32-23LW & will not be reqd to purge the reel wi N2. 15. Leave Flowback tank rigged up while well is producing acid load. 16. Start up gas lift slowly as to what the PTS tank can handle. Flow load back to PTS tan1e Once load is recovered & fluid is acceptable, turn well to the header system and put well in test. Monitor the well for ±3 days taking readings every other hour. Put well back into regular test rotation after 3-4 days. . Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. . 9cJ cJ. ¥ Paul Figel Engineering Manager ¥o Kyle Hammond Vice President Operations, Alaska Procedure 4-1-05 · " '~TO ~kRGY MGS C21A-23 Cook Inlet, Alaska Leg 4, Conductor 27 API No.: 50-733-20219-02 Orig Well was C11-23 Sidetracked: 5-11-91 Conductor: 24" , Set @ 370'. Surf Csg: 13-3/8" 54.5# K55 BTC. Set @ 1,438'. Cmt'd wI 520 sx. Intermediate: 9-5/8" L-80 LTC. Window Milled @ 9320'. Surf - 4176' : 43.5# 4176'-9320' : 47# TOC ±8847'. Drilling Liner: 7" 26# L80 LTC. Set @ 11,410', TaL @ 8,726'. Cmt wI 2,575 sk. Production Liner: 5" 18# N80 FL4S. Set @ 12,290'. TaL @ 11,206'. Cmt wI 300 sx. ') Present Completion ~ J J J J J J J J fit J ~ = I -- -=-1 , ;;>;~' , , %: ~ Y"/ ?¿ ~ ~ 1'/,\ ~ ;;,.1 ~ 77!í // //1 ~ .-- ~~ Fish: GLV dropped 12-31-95 FILL: (None as of 3-12-04) PBTO: 12,286' MD TD: 12,290' MD (9,719' TVD) ) PLF 3-31-05 KB: 35' Water Depth: 73' MSL Tbg: 2 7/8" 6.5# L80 8R EUE @ 11,199' Set: 7-25-91 Item MD TVD ptro Port GLM#1:1839i ·1828' 981 12 'GL..rvf#2 3677' :3398'··' 964 12 <3.~~"~!~ ,54?"~' .4742' 1000 16 <:7..~.~... ~j,~~~O' · 5899' 948'12 GLM #5: 8124' 5802' 998 16 1""",,_...,-- ...,","",....,1".. ,_, ,..........,..,. ,<3~~~?'~99~':!~00' 998 16' :<3~~~7 ,~6~7' \~OÖÖï' 1100 20: .....<3L'rvi· #~:1q~~~':~~'q~' ...............1g~~'....I.......20 \ I GLrvi #9: 11064'! 8980i·.1/4" orifice' 2-7/8" SSSV (2.313" ID) @ 327' Òfis"XQ" SlidingSleeve@"11,'1Ö9ì.. 1\~9~()r,~~~I. ~s~y . "11,144' : Baker SB-3 Packer ' 11,145'. Millout Extension ·11,149' ºti~ "~i'~iEpl~(2:20~" 10) 11,~~!' 'WL Entry Guide 11,19'9'· Perf'd @ 4 spf: 577' Net (2,308 holes) HC-HD: 11,415'-11,460' HD-HE: 11,490'-11,508' HE-HF: 11,564'·11,636' HI-HK: 11,734'-11,764' HK-HN: 11,786'-11,990' HN-HR: 12,008'-12,108' HN-HR: 12,140'-12,176' HR-HZ: 12,208'-12,280' ON OR BEFORE c:LOglXMI~LId.DOC Cross Timbers Operating COmpany August 23, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN: MR. BLAIR WONDZELL SUBJECT: SUBMISSION OF FORM 10-404 REPORT OF SUNDRY WELL OPERATIONS - ACID TREAT M.G.S. WELL NO. C21A-23 Attached, in duplicate, is the Report of Sundry Well Operations for MGS Well No. C21 A-23. The workover included cleaning out the scale and paraffin with 7-1/2% HC1. If you have any questions, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, Bill Miller Office Manager Attachments HC01 Box 485, Old Wik Road, Kenai, AK 99611-9704 Onshore phone: (907) 776-2511, Onshore fax: (907) 776-2542 Platform A fax: (907) 776-2522, Platform C fax: (907) 776-2532 www. crosstimbers.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown-- Stimulate X Plugging-- Perforate-- Pull tubing __ After casing_ Repair well Other 2. ~ameof~pe,rator uross limpers 0peratinfl Company 3. Address 52260 Shell Road Kenai, AK 99611-9704 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface Leg4, Cord. 27, 509' FSL&1532' FEL o¢ Sec.23,T8N, R13W,SM At top of productive interval 344'FNL & 3701'FEL of Sec. 23, T8N, R13W, SM At effective depth At total depth 219'FSL & 2845'FEL o¢ Sec. 14, T8N, R13W, SM 6. Datum elevation (DF or KB) 105' KB 7. Unit or Property name Hiddle Ground Shoal feet 8. Well number C21A-23 9. Permit number/approval number 91-44 / 399-129 10. APInumber~ 50- 733-20219-02 11. Field/Pool MGS "G" Pool 12. Present well condition summary Total depth: measured 12290 feet true vertical 9719 feet Plugs (measured) Effective depth: measured 12286 feet true vertical 9717 feet Junk (measured) Casing Length Size Structural Conductor 380' 24" Surface 1438' 13- 3/8" Intermediate Production 9282' 9- 5/8" Liner 3565' 7" & 5" Perforation depth: measured 11415' - 12280' true vertical 9204' - 97O9' Tubing(size, grade, and measured depth) 2-7/8", 6.5#, L80 8R EUE to 11199' Packers and SSSV(fype and measured depth) Baker SB-3 packer @ 11145'. Cemented Measured depth 520 sx G O' 1438' 300 sx G O' - 9320' 2875 sx G 8726'-12290' ORIGINAL SSSV @ 302" True vertical depth 13. Stimulation or cement squeeze summary Intervals treated (measured) 11408' - 12280' Treatment description including volumes used and final pressure Clean out & acid treat with HCl, 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 30 9 0 470 Subsequent to operation 58 24 0 820 Tubing pressure 70 7O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended_ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ WilliamA. Miller Signed Title Office Manager Date Form 10-404 Rev O6/15/88 - 44- SUBMIT IN DUPLICATE DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: C21A-23 AFE #: 99396 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62272 CLASSIFICATION: CLEAN OUT SCALE AND PARAFFIN BUILD UP DESCRIPTION: PLATFORM C COOK INLET CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: 08/02/99 08/03/99 FIRST REPORT. Objective: Clean Out Scale & Paraffin Build Up. Date First Report: 08/02/99. 32 hrs RD off Platform A & move to Platform C. Start RU. DCC: $9000 CCC: $9000 Finish RU. Test lines & BOP's to 4500 psi. Test CT & tools to 4200 psi. Make up BHA: Grapple connector, check vlv, x-over, hydraulic disconnect, pce circ vlv, dwnhole filter, swvl jt w/1.90" gauge ring, rotating nozzle head (2 side jets @ .125", no dwn jet), total length 8.145'. TIH w/BHA on 1 3/4" CT while circ 1 BPM & 38 fpm. Did not tag any obstructions but it did appear to be pushing something ahead of the CT. SD solid @ 12241', wash to 12242'. Unable to wash deeper. Top perf 11415'. Btm perf 12280' PU to 11686', jetting across perfs. Wash back to btm while jetting w/FIW. Switch to acid. Spot 14 bbl of 7 1/2% HC1 plus additives across perfs. Jet w/FIW while POH @ 10-15 fpm across perfs. Circ out of hole using FIW. Added H2S scavenger while acid reached surf. Circ btms up twice. Max H2S in return fluid was 120 ppm. Max reading in tnk was 4000 ppm. Out of 14 bbl of acid pmpd, 10 bbl of returns had an acid concentration of 5% to 6 1/2% (titration method). Returns were dark gray to black wtr. No solids. TIH to 12216' Pmp 48 bb! of xylene and spot 15 bbls across perfs. PU to 11408'. Close BOP's & sqz 33 bbl xylene into perfs. Pmp @ .57 bpm & 4438 psi on CT & 3434 psi on surf. Leave 15 bbl xylene across perfs. Pmpd a total of 651 bbl of FIW, 14 bbl of 7 1/2% HC1 & 48 bbl of xylene. POH. RD Dowell. Turn well to test. DCC: $61,600 CCC: $70,100 DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: C21A-23 AFE #: 99396 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING %: 62272 CLASSIFICATION: CLEAN OUT SCALE AND PARAFFIN BUILD UP DESCRIPTION: PLATFORM C COOK INLET CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: 08/04/99 24 hr test. Time Fluid Fluid per/hr Wtr cut Csg Press Total Fluid 0100 1200 35 35 93 805 35.0 1400 4 2 96 805 39.0 1600 6 3 80 45.0 1800 9.4 4.7 99 54.4 2000 3.8 1.9 75 58.2 2200 8 4 99 66.2 2400 10.7 5.3 50 76.9 0200 2.4 1.2 50 79.3 DCC: $-0- CCC: $70,100 08/05/99 Put well in test. Appears to lifting on 4th GI.V. Attempting to work dwn hole. Time Fluid Fluid per/hr Wtr cut Csg Press Total Fluid 0400 4.4 2.2 68 0600 2.3 1.2 8.5 080O .4 .2 1000 0 0 1200 2.7 1.4 58 DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: C21A-23 AFE #: 99396 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62272 CLASSIFICATION: CLEAN OUT SCALE AND PARAFFIN BUILD UP DESCRIPTION: PLATFORM C COOK INLET CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: DCC: $- 0- CCC: $70,100 08/06/99 Well unloading. Test well for 74 hfs (24 hr rates): Gross 106 BFPD, Cut .1%, 106 BOPD, 1 BWPD. CP 810 psi. DCC: $-0- CCC: $70,100 08/07/99 Corrected report for 08/05/99. 7 hr test (24 hr rates): Gross 31 BFPD, Cut 1%, 31 BOPD, 0 BWPD. No gas reported. CP 810 psi. 12 hr test (24 hr rates): Gross 46, wtr cut 70%, 14 BOPD, 56 BWPD, 66 MCF/D, Inj Gas 611 MCF/D. TP 70 psi, CP 805 to 840 psi. Trying to unload & work gas inj dwnhole. DCC: $-0- CCC: $70,100 08/08/99 12 hr test (24 hr rates): Gross 48 BFPD, Cut .5%, 48 BOPD, 0 BWPD, 20 MCF/D, Inj Gas 921 MCF/D. TP 70 psi, CP 840 psi. DCC: $-0- CCC: $70,100 08/09/99 12 hr test (24 hr rates): Gross 43 BFPD, Cut 1%, 43 BOPD, 0 BWPD, 7 MCF/D, Inj Gas 921 MCF/D. TP 70 psi, CP 630 psi. DCC: $-0- CCC: $70,100 08/10/99 12 hr test (24 hr rates): Gross 39 BFPD, Cut 0.5%, 39 BOPD, 0 BWPD, 17 MCF/D, Inj Gas 921 MCF/D. TP 70 psi, CP 820 psi. DCC: $-0- CCC: $70,100 08/11/99 Testing other wells. DCC: $-0- CCC: $70,100 DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: C21A-23 AFE #: 99396 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62272 CLASSIFICATION: CLEAN OUT SCALE AND PARAFFIN BUILD UP DESCRIPTION: PLATFORM C COOK INLET CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: 08/12/99 Testing other wells. DCC: $-0- CCC: $70,100 08/13/99 Testing other wells. DCC: $-0- CCC: $70,100 08/14-16/99 Testing other wells. DCC: $-0- CCC: $70,100 TEMPORARILY DROP WHILE TESTING q.,ross · ,mners upera~lng uompany Present Completion MGS C 21A-23 Cook Inlet, Alaska Leg X, Conductor x APl No.: Spud: Conductor: 24", Set @ 380'. Cmt'd wi Surf Csg: 13 3/8", 54.5 lb, K55 BTC. Set @ 1,438'. Cmt'd w/300 sx. Class "G"+ 10% gel at 12.8 ppg & 220 sx. Class "G" at 15.8 PPg. Protective Csg: 9 5/8", 43.5 lb, L80 LTC 39'-4178'. 47# L80 LTC 4176'-9320'. Cmt'd wi Window in Exsisting Cl 1-23 Csg. 9320'-9400' (Designed TOC at 8847' +/-) Intermediate Liner Csg: 7", 26 lb, L80 LTC Linear. Set @ 11,410', TOL @ 8,726'. Cmt w/ Production Liner Csg: 5", 18 lb, N80 FL4S Linear. Set @ 12,290', TOL @ 11,208'. Cmt w/300 sx. Class "G" at 15.6 ppg. PBTD: 12,286' TD: 12,290' (MD) - 9,719' (TVD) KB: ' Water Depth: Tbg: 2 7/8" 6.5# L80 8R EUE. EOT @ 11,199' Item TVD MD Ptro Port Gas Lift Mandrel #1 1828' 1839' 981 12 Gas Lift Mandrel #2 3398' 3677' 964 12 Gas Lift Mandrel #3 4742' 5454' 948 12 Gas Lift Mandrel #4 5899' 6980' 1000 16 Gas Lift Mandrel #5 5802' 8124' 998 16 Gas Lift Mandrel #6 7500' 9003' 998 16 Gas Lift Mandrel #7 8000' 9667' 1100 20 Gas Lift Mandrel ~ 8506' 10396' 1099 20 Gas Lift Mandrel ~9 8980' 11064' 114" Orifice MD TVD Otis "XO" Sliding Sleeve @ 11,109' 9,010' Anchor Seal Assy 11,144' 9,034' Baker SB-3 Packer 11,145' 9,034' Millout Extension 11,149' 9,037' Otis "XN" Nipple 11,187' 9,062' WL Entry Guide 11,199' 9,070' HC-HD: 11,415'-11,460' HD-HE: 11,490'-11,508' HE-HF: 11,584'-11,626' HI-HK: 11,734'-11,764' HK-HN: 11,786'-11,990' HN-HR: 12,008',12,108' HN-HR: 12,140'-12,176' HR-HZ: 12,208'-12,280' Cross Timbers Operating Company July 12, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO ACID TREAT M.G.S. WELL NO. C21A-23. Enclosed in triplicate is the Application for Sundry_ Approval, Form 10-403, to stimulate MGS C21A-23 utilizing 7-1/2% HC1. Operations are expected to begin August 1, 1999. If you have any questions, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, Bill Miller Office Manager Attachments Anchorage HC01 Box 485, Old Wik Road, Kenai, AK 99611-9704 Onshore phone: (907) 776-2511, Onshore fax: (907) 776-2542 Platform A fax: (907) 776-2522, Platform C fax: (907) 776-2532 www. crosstimbers.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation shutdown Re-enter suspended well __ After casing ~ Repair well Plugging~ Time extension ~ Stimulate X Change approved program Pull tubing ~ Variance .~ Perforate ~ Other 2. Name of Operator Cross Timbers 0peratin,q Compan,y 3. Address HC01 Box 485 01d Wi k Rd Kenai AK 99611-9704 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of Well at surface "C", Leg 4, Cord. 27, 509'FSL & 1532'FEL of Sec.23, T8N, R13W, SM At top of productive interval 6. Datum elevation (DF or KB) 105' KB 7. Unit or Property name Middle Ground Shoal 8. Well number C21A-23 9. Permit number 91-44 10. APl number 5o- 733-20219-02 344'FNL & 3701'FEL of Sec. 23, T8N, R13W, SM At effective depth At total depth 219'FSL & 2845'FEL of Sec. 14, T8N, R13W, SM 11. Field/Pool MGS "G" Pool feet 12. Present well condition summary Total depth: measured true vertical 12290 feet Plugs (measured) 9719 feet Effective depth: measured true vertical 12286' feet Junk (measured) 9717' feet Casing Length Structural Conductor 380 Surface 1438 Intermediate Production 9282 Liner 3565 Perforation depth: Size 24" 13- 3/8", 54.5~, K- 55 9-5/8" 7" & 5" measured 11415' - 12280' true vertical 9204' - 9709' Tubing (size. grade, and measured depth) 2-7/8", 6.5#, L80 8R EUE to 11199' Cemented Measured depth True vertical depth 520 sx "G" O' - 1438' 300 sx "G" O' - 9320' 2875 sx "G" 8726' - 12290' 0 / Packers and SSSV (type and measured depth) Baker SB-3 packer @ 11145' SSSV @ 302'. 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 8/01/1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas ~ Service Suspended 17. I hereby/~ertif~h~e and correct to the best of my knowledge. Signed ~/~/L~,/[-"~y~ Title Office Manager Date 7/12/1999 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so ~epresentative may witness Plug integrity BOP Test J Location clearance IApproval NO. Mechanical Integrity Test __ Subsequent form required 10- /~'OLt¢ ORIGINAL SIGNEDBY Approved by order of the Commission Robert N. Chdstenson Form 10-403 Rev 06/15/88 n,4e(~ O:~''~ ~ ~,~ornmissioner SUBMIT IN TRIPLICATE CROSS TIMBERS OPERATING COMPANY MGS C21A-23 COOK INLET, ALASKA ELEVATION: WELL DATA SURFACE CASING' PRODUCTION CASING: LINER: LINER: TUBING: PERFORATIONS: OBJECTIVE: TD: 12290' (MD) 9719' (TVD) PBTD: 12288' (MD) 13 3/8" 54,5# K55. Set ~ 1438'. Cmt w/300 sx G 10% gel(12.8 ppg) & 220 sx G (15.8 ppg). 9 5/8" 43.5(39-4176'), 47(4176-9320')# LB0. Set at 9320'. 7" 26 # L80. TOL ~ 8725'. Set ~ 11410'. Cmt w/2575 sx G (15.5 ppg). 5" 18# NS0 FL4S. TOL ~ 11206'. Set ~ 12290. Cmt w/300 sx G (15.6 ppg). 2 7/8" 6.5# L80 8R EUE ~ 11199' HC-HD 11415-11460' HD-HE 11490-11508' HE-HF 11564-11636' HI-HK 11734-11764' HK-HN 11786-11990' HN-HR 12008-12108' HN-HR 12140-12176' HR-HZ 12208-12280' Remove scale and paraffin buildup using Coiled Tubing 1. One week prior to RU CT, tag btm w/SL. Note all tight spots. . o MIRU Dowell CTU and pump. Test lines to 5000#. TIH w/jetting tool to PBTD ~ + 12288'. Jet well c-- .lean__:u, sin.~. Wash perfs using 500 gal of 7 ½% HC1. Work CT across perfs.~ well cluing FIW. Displace xylene to EOT. Close surface valves. Spot xylene across per/~ fr0m'l i'415-12~280'. Displace 2000 gal of xylene into perfs. POOH w/CT. RD Dowell CT. Allow to soak 4 hrs. GL well back. Obtain samples of all fluids for Dowell to analyze for live acid. Cross Timbers r~'~,erating Company Present Completion MGS C 21A-23 Cook Inlet, Alaska Leg X, Conductor x APl No.: Spud: Conductor: 24", Set @ 380'. Cmt'd w/ Surf Csg: 13 3/8", 54.5 lb, K55 BTC. Set @ 1,438'. Cmt'd w/300 sx. Class "G" + 10% gel at 12.8 ppg & 220 sx. Class "G" at 15.8 PPg. Protective Csg: 9 5~8", 43.5 lb, L80 LTC 39'-4178'. 47# L80 LTC 4176'-9320'. Cmt'd w/ Window in Exsisting C11-23 Csg. 9320'-9400' (Designed TOC at 8847' +/-) Intermediate Liner Csg: 7", 26 lb, L80 LTC Linear. Set @ 11,410', TOL @ 8,726'. Cmt w/ Production Liner Csg: 5", 18 lb, N80 FL4S Linear. Set @ 12,290', TOL @ 11,208'. Cmt wi300 sx. Class "G" at 15.6 ppg. PBTD: 12,286' TD: 12,290' (MD)- 9,719' (TVD) btr: 5/11/99 KB: ' Water Depth: Tbg: 2 7/8" 6.5# L80 8R EUE. EOT @ 11,199' Item TVD MD Ptro Port Gas Lift Mandrel #1 1828' 1839' 981 12 Gas Lift Mandrel #2 3398' 3677' 964 12 Gas Lift Mandrel #3 4742' 5454' 948 12 Gas Lift Mandrel #.4 5899' 6980' 1000 16 Gas Lift Mandrel #5 5802' 8124' 998 16 Gas Lift Mandrel #6 7500' 9003' 998 16 Gas Lift Mandrel #7 8000' 9667' 1100 20 Gas Lift Mandrel #8 8506' 10396' 1099 20 Gas Lift Mandrel #9 8980' 11064' 1/4" Orifice MD TVD Otis"XO" Sliding Sleeve @ 11,109' 9,010' Anchor Seal Assy 11,144' 9,034' Baker SB-3 Packer 11,145' 9,034' Millout Extension 11,149' 9,037' Otis "XN" Nipple 11,187' 9,062' WL Entry Guide 11,199' 9,070' HC-HD: 11,415'-11,460' HD-HE: 11,490'-11,508' HE-HF: 11,584'-11,626' HI-HK: 11,734'-11,764' HK-HN: 11,786'-11,990' HN-HR: 12,008',12,108' HN-HR: 12,140'-12,176' HR-HZ: 12,208'-12,280' September 3, 1991 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT' SUBMISSION OF WELL COMPLETION REPORT AND LOG FOR WELL C21A-23 Enclosed, in duplicate, is the Well Completion Report and Log for Well C21A-23. The spud date for C21A-23 was May 11, 1991 and total depth was achieved on July 17, 1991. The well was put on production July 25, 1991. If you have any questions, please call Mr. Paul Huckabee or Ms. Susan Brown-Maunder at (907) 276-2545. Very truly yours, V. E. Unger Division Drilling Engineer Alaska Division VEU/slm Enclosures aogcc/compl ete. doc ALASKA OIL AND GAS CONSERVATION COrvqMISSION )L/ , WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Well OIL .~ GAS [] SUSPENDED [] ABANDONE 2. Name of Opera~°r VF'~'IF[~F'D I ~ ~.~,v:,-~ ...... ~ I 7. Permit Number 4. ~oo~,io, of~,,~ts,;¢~o, Platform C, Leg 4, 6onductor Z532' FEL of Sec. 23, T8N, Ri3~, A.S.P. ~idd]e 6round Shoal At Top Producing lnterval 344' FNL & 370~' FEL of Sec. 23, T8N, RZ3~, ~O.W~N~b.r A.S.P. C2~A-23 At Total Dep,h2Z9' FSL & 2845' FEL of Sec. t4, T8N, R~3~, A.S.P. 11. Field and Pool "6" Pool 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. Z05' KB ~ ADL-Z8756 12. Date Spudded 13. DateT.D. Reached ~ 14. Date Comp.,Susp. orAband. ~15. Water Depth, if offshore ~16. No. of Completions 5/1~/9~ 7/~7/91 ' ' ' SSSV set [ 21. Thickness of Permafrost 18.Plug Back Depth (M~D)~ 19. Directional Survey 20. Depth where 12,286' & 971'7' IYES~ NO~ 302 feetMD I N/A Atlas Wireline 23. 17. Total Depth (MD+TVD) 12,290' & 9719' 22. Type Electric or Other Logs Run DLL/ACOU/GR/SP/MLL/CAL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 0 1438' K-55 L-80 54--~ 17 & 43.5 9320' HOLE SIZE 11,410' 12,290' 13-3/R" 9-5i~" 7"Liner 26 L-80 8726' 5"Liner 18 N-80 11,206' 24. Perforations open to Production (MD+TVD of Top and Bottom and 17-1/2" 12-1/4" 8-1/2" 6-1/4" t CEMENTING RECORD /AMOUNT PULLED 520 sx "G" + add .Window in-existing ~asing 2575 sx "G" + add 300 sx "G" + add 25. TUBING RECORD interval, size and number) A11 4 MD 11,415 11,490 11 564 11 734 11 786 11008 12 140 12 208 -12 -11 460 636 -11 764 -11 990 -12 108 -12 176 280 JSPF: TVD 9204'-9232 9250'-9261 9295'-9337 9395'-9412 9425'-9543 9553'-9613 9629'-9650 9668'-9709 SIZE DEPTH SET (MD) I PACKER SET (MD) 2-7/8" 11,199' I 11,145' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production 7/27/91 Date of Test 7/30/91 Flow Tubing Press. 90 Hours Tested 24 Casing Pressure 520 28. Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR IOI L-BBL ! GAS-MCF TESTPER~OD ~ I 152 47 CALCULATED I OIL'BBL I GAS-MCF 24-HOUR RATE eI 152 47 CORE DATA WATER-BBL 2 WATER-BBL 2 I CHOKE SIZE IGAS'OILRATIO 2" I 309 scf/bo OIL GRAVITY-APl (corr) 35.7 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. SEP - 51991 Form 10-407 Submit in duplicate _ 29. 30. GEOLOGIC MARKr: ,*~JRMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH .... ! TRUE VERT. DEPTH GOR, and time of each phase. "G" Pool 11,393' 9191' 31. LIST OF ATTACHMENTS Daily Report of Operations, We]] Bore Diaqram, BOP Test Results (Hard £onv) I he~ certify that the foregoing is true and correct to the best of my knowledge ---'~ Title Div. Drlg. Eng. Date 8/30/91 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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 OTIS 'XXO' SSSV at 327' GAS LIFT MANDRELS: NO MD TVD I 1839' 1828' 2 3677' 3398' 3 5454' 4742' 4 6980' 5899' 5 8124' 6802' 6 9003' 7500' 7 9667' 8000' 8 10,396' 8506' 9 11,064' 8980' MGS C21A-23 PRESENT STATUS 7/24/91 TUBING.' 2-7/8' 6.5# L-80 EUE 8rd 35' - 11,199' ITEM MD TVD OTIS "XD' SLEEVE 11,109' 9010' ANCHOR SEAL ASSY 11,144' 9034' BAKER SB-3 PACKER 11,145' 9034' MILLOUT EXTENSION 11,149' 9037' OTIS "XN' NIPPLE 11,187' 9062' WL ENTRY GUIDE 11,199' 9070' WAM/C21A PERFORATIONS: HC-HD 11,415' - 11,460' HD-HE 11,490' - 11,508' HE-HF 11,564' - 11,636' HI-HK 11,734' - 11,764' HK-HN 11,786' - 11,990' HN-HR 12,008' - 12,108' HN-HR 12,140' - 12,176' HR-HZ 12,208' - 12,280' -23.CHT I TD at 12,290' MD (9719' TVD) 24' CONDUCTOR at 360' 13-3/8' SURFACE CASING at 1438' 54.5# K-55 BTC CEMENTED w/ 300 sx "G' + 10% GEL at 12.8 ppg & 220 sx "G' at 15.8 ppg 7' TOL at 8726' 9-5/8' PROTECTIVE CSG at 9320' 43.5# L-80 LTC 39' - 4176' 47# L-80 LTC 4176' - 9320' WINDOW in EXISTING Cll-23 CSG: 9320' - 9400' (DESIGNED TOC at 8847'*/-) 5" TOL at 11,206' 7' INTERMEDIATE LINER at 11,410' 26# L-80 LTC CEMENTED w/ 2575 sx 'G' at 15.5 ppg PBTD at 12,286' 5" PRODUCTION LINER at 12,290' 18# N-80 FL4S CEMENTED w/ 300 sx 'G' at 15.6 ppg DAILY REPORT OF ACTIVITIES C21A-23 DATE ACTIVITY 051291 NIPPLE DOWN RENTAL DOUBLE GATE BOP. NIPPLE UP RIG'S DBL GATE BOP. CASING WAS TESTED (WHILE WELL NAME WAS Cll-23) T/3700 PSI F/30 MINS OK PRIOR T/NIPPLE DOWN. DID WEEKLY LOW/HIGH PSI BOPE TEST. HCR FAILED TO TEST. REPLACED W/MANUAL OPERATED 3.1125" 5M VALVE. NEW VALVE TESTED OK M-U SERVCO CSG MILL/BHA. TIH. FOUND TOP OF CMT PLUG AT 9614'. PULLED BACK UP T/9320' TO MILL WINDOW. MILLING W/MILL #1 F/9320' T/9325'. MILLING AHEAD AT RPT TIME. 051391 ALTERNATELY MILLING THEN WORKING OUT "BIRDS NEST" F/9325' T/9400'. HAD 11 HRS ACTUAL "ON BOTTOM" MILLING TIME FOR 75'. CIRC HOLE UNTIL CUTTINGS QUIT COMING OVER SHAKERS. POH W/MILL. WAS TIGHT PULLING THE FIRST 2500~ OFF BTM, SOME DRAG ON UP ALSO. CUTTERS WERE WORN COMPLETLY OUT. LAYING DOWN MILL AT RPT TIME. 051491 FINISHED LAYING DOWN SERVCO MILL. M-U MULE SHOE ON END OF 450~3.5'' TBG TIH T/9535'. BREAK CIRC. (HOWCO PLUG CATCHER AT TOP OF TBG) TBG PLUGGED. ATTEMPT TO CLEAR PLUG BY REVERSING AND CONVENTIONAL CIRC. NO SUCCESS. POH W/WET STRING. CLEARED METAL CUTTINGS/WALL CAKE ETC F/TBG TO DP XO AREA AND HOWCO PLUG CATCHER. (5 GALLON BUCKET FULL) TIH W/MULE SHOE ON END OF 5" DP T/9510~. CIRC W/700 GPM, PUMPED HI-VIS SWEEP, RECOVERED 3/4 OF 55 GAL DRUM OF METAL CUTTINGS/WALL CAKE ETC. POH W/DRILL PIPE. MAKE UP CEMENTING ASSMY, TIH T/4800'. CIRC A PIPE VOL T/ASCERTAIN PIPE STILL OPEN. TRIPPING ON IN HOLE AT REPORT TIME. 051591 TIH T/9485'. CDL 100'. RIH T/9517', CIRC/COND F/CEMENT. PERFORMED LEAK-OFF TEST, CSG SHOE AT 9320'. 14.33 PPG EMW AT 7750 TVD. RIG HOWCO LINES, PUMPED 5 BBLS WATER AHEAD TEST LINES T/3500 PSI. OK PUMPED 35 BBLS MORE FRESH WATER AHEAD. HOWCO BULK FEED CMT LINES PLUGGED OFF. CLEANED OUT LINES. PUMPED 200 SX CLASS "G" CMT + .30% CFR-3, +.22 HR-7, 36 BBLS SLURRY. 1.02 YIELD, 16.7 PPG. FOLLOWED W/5 BBLS FRESH WATER, DISPLACED W/155 BBLS OF MUD. CIP AT 1225 HRS, 05/14/91. EST TOC AT 9200'. POH UP T/8595'. REVERSE OUT 1.5 PIPE VOL'S. DROP WIPER PLUG, PUMPED IT INTO CATCHER. POH. CHIPPED CEMENT FROM INSIDE, BOTTOM OF TOOL JTS OF LAST 96 JTS DP. TIN W/EXTRA DC/HWDP/DP IN DERRICK. SLIP ON NEW DRILLING LINE. REPLACED WORN LINE GUIDE ROLLER. POH LAYING DOWN EXTRA TUBLARS. CHOKE LINE AT RPT TIME. SEP - 5199 051691 FINISHED REPLACING CHOKE LINE VALVE/HCR VALVE. TEST PER SPEC'S. OK. M-U KICKOFF BHA, SURFACE TEST MWD, OK, TIH. TAG CEMENT AT 9212'. CLEAN OUT FIRM CEMENT F/9212' T/9325'. TIME DRILLING OFF OF PLUG F/9325~ T/9338' 051791 TIME DRLG F/9338' T/9358~. AT 9358~ PLUG WAS MUSH. PUMPED DOWN TO ENGAGEMENT W/CSG STUB AT 9396' W/NO RESISTANCE. CIRC OUT THICK CMT CONTAMINATED MUD. POH. LAYED DOWN MUD MOTOR. PICKED UP 3.5" TBG STINGER, PLUG CATCHER AND TIH AT RPT TIME TO LAY KICKOFF PLUG. BIT #1COND: O-O-1CT-N1-E-I-N-HP 051891 FINISH TIH W/TBG STINGER. TAGGED BTM AT 9396'. CIRC/COND F/CEMENT. RIG HOWCO LINES. PUMPED 5 BBLS FRESH WATER AHEAD. TEST LINES T/3500#. OK. PUMPED 35 BBLS FRESH WATER AHEAD OF 160 SX CLASS "G" CEMENT + .30% CFR-3 + .22% HR-7. 15 BBLS MIX WATER, 29 BBLS SLURRY, 4.0 GALS/SX, 1.02 YEILD, 16.7 PPG. 5 BBLS FRESH WATER BEHIND, DISPLACED W/155 BBLS 9.4 PPG MUD. CIP AT 1015 HRS 05/17/91. PULLED UP T/8540~ REVERSED OUT 1.5 ~IPE VOL~S. DROP WIPER PLUG, PUMPED IT INTO CATCHER. FINISHED POH. LAYED DOWN EXCESS DRILL PIPE AND TBG STINGER. M-U KICK- OFF BHA. TIN. TAGGED SOFT CMT AT 9144~. DRILL SOFT TO FIRM CEMENT F/9144~ T/9170~. DRILL HARD CEMENT F/9170' T/9325'. ORIENT MUD MOTOR. TIME DRILLING OFF OF PLUG F/9325' T/9330'. HELD TRIP DRILL W/EVE TOUR CREW. WELL SECURED IN 90 SECEONDS. 051991 MUD MOTOR OFF OF PLUG F/9330' T/9360'. REQUESTED VARIANCE TO POSTPONE BOPE TESTING UNTIL NEXT TRIP. 052091 DRLG F/9360 T/9710' W/MUD MOTOR/MWD. USING ROTARY AS NEEDED. 052191 DRLG F/9710' T/9723' W/MUD MOTOR/MWD. CHECK F/FLOW, NONE. POH,LAY DOWN MOTOR/MWD. DID WEEKLY BOPE TEST. OK. MAKE UP NEW BHA F/ROTARY DRILLING. TIH T/9300'. CHANGED OUT MUD SYSTEM T/INLET WATER BASE VS FRESH WATER BASE. RUN IN HOLE WITHOUT PUMP/ROTARY T/9429' (29' PAST CSG STUB AT 9396'.) REAMED ON T/BOTTOM AT 9723'. DRLG F/972~' T/9885' W/BIT #2. NOTE: HELD TRIP DRILL W/MORN TOUR CREW; WELL SECURED IN 60 SECONDS. BIT #IRR COND: 2-2-WT-A-E-1-ER-HR/BHA 052291 DRLG F/9885' T/9933' W/BIT #2. WIRELINE SURVEY. DRLG F/9933' T/10430' W/BIT #2. FRESH WATER USED TODAY:50 BBLS CUMULATIVE USED ...... 475 BBLS (425 USED TO PRE-HYDRATE GEL FOR NEW MUD SYSTEM) 052391 DRILLING TO 10,480 W/BIT #2. SURVEY AND TRIP FOR BIT WASH AND REAM 60' TO BOTTOM, NO FILL. DRILLING W/BIT #3 TO 10,793' CIRCULATE. DROP SURVEY AND PULL TO SHOE FRESH WATER USED TODAY 270 CUMULATIVE 745 AOGCC \C 21A23DR. DOC 052491 REAM UP THROUGH TIGHT HOLE ENCOUNTERED WHILE PULLING TO SHOE TO RECOVER SURVEY (9753~) POH RECOVER SURVEY, RIH DRILLING W/BIT #3 TO 10867~ TRIP FOR DIRECTIONAL CONSIDERATIONS. WORK THROUGH TIGHT HOLE AT 9750. LAY DOWN ROTATING ASSEMBLY, PICKUP DRILEX MOTOR AND I 1/2 DEGREE BENT SUB. RIH. MWD SURVEY AND ORIENT MOTOR DRILLING TO 10908~ AT 0600 FRESH WATER USED TODAY 0 CUMULATIVE 745 052591 DRILLING DIRECTIONALLY W/MUD MOTOR AND ANADRILL MWD. (WORK OUT OF TIGHT HOLE BY UP REAMING FROM 11,065 TO 11,055) FRESH WATER 0 CUMULATIVE 745 052691 DRILLING W/ MUD MOTOR TO 11,204~ TRIP FOR ROTATING BHA, CDL, RIH TO 10,833~ TO BEGIN REAMING REAMING FRESH WATER USAGE 0 CUMULATIVE 745 052791 REAM MUD MOTOR RUN TO 11,204~ DRILLING W/BIT #5 TO 11,336~ DRILLED APPROX. I FT. INTO COAL IMMEDIATLY ABOVE HC, TORQUE INCREASED, UNABLE TO PICK UP. BIT STUCK ON BOTTOM. WORK STUCK PIPE, JARRING AND ATTEMPTING TO TURN. RIG UP DIA-LOG RIH W/ FREE POINT INDICATOR/STRING SHOT, HAVING SOME DIFFICULTY GETTING DOWN THROUGH HWDP (PROBABLY DUE TO 50 DEGREE ANGLE) TOP MONEL FREE, WORKING DOWN LEFT HAND TORQUE AT REPORT TIME, WILL ATTEMPT TO RECOVER TOP MONEL. FRESH WATER USED 0 CUMULATIVE 745 052891 WORK LEFT HAND TORQUE INTO STRING AND SHOOT OFF BETWEEN TOP TWO MONEL DC~S POH, (REPLACE GOOSE NECK) LAY DOWN RECOVERED BHA (JARS,STB,MONEL) PICKUP FISHING ASSEMBLY (SCREW IN SUB, JARS, 6 DC~S, ACCELERATORS) RIH, CUT & SLIP 200~ DRLG LINE, PICKUP KELLY AND BREAK GOOSE NECK BULL PLUG. CIRC AND COND. 30~ ABOVE FISH. SCREW INTO FISH AT 11,257~ JAR AND WORK FISH 4 HOURS W/ NO SUCCESS PUMP PRESSURE LOSS WHILE SCREWED INTO FISH INDICATES LEAK IN STRING MOST PROBABLY SHOT DRILL COLLAR ON FISH. RIH WITH STRING SHOT, BACK OFF FISHING STRING, POH W/ WIRELINE. MIX AND SPOT 17 PPG 20 BBL PILL ON TOP OF FISH. POH, LAY DOWN FISHING STRING. NO FRESH WATER USED, CUMULATIVE 745 052991 LAY DOWN FISHING TOOLS TEST B.O.P. PICKUP MULE SHOE AND 15 JTS. 3 1/2" TUBING, RIH TO 11,249 CIRC. AND COND. MUD FOR PLUG PUMP 5 BBLS H20, TEST LINES TO 3,000 PSI, PUMP 35 BBLS H20, 250 SX. PREMIUM CMT. (45 BBLS) MXD AT 16.7 PPG.(BLENDED W/.3% CFR2 AND .17% AOGCC \C 21A23DR. DOC HR7) 2 BBLS H20. DISPLACE W/ 191BBLS. 9.6 PPG. MUD. CIP @ 1630 HRS HOWCO GOT GOOD MIX ON PLUG W/ NO LIGHT SPOTS. PIPE PULLED DRY, PLUG BALANCED PERFECTLY. POH TO CSG. SHOE. CIRC. TO CLEAN DRILL STRING POH LAY DOWN TUBING, PICKUP KICKOFF ASSY. W/BIT #6 KELLY IN SINGLES, TIGHT SPOTS/BRIDGES F/9930 T/10028, F/10181 T/10294 TAG TOP OF PLUG AT 10894 (363~0F CMT.) TOOLS SIDETRACKED IN HOLE DESCRIPTION 6 1/4 X 8 1/2 NB STAB. NON-MAG LC 6 1/4 X 10~ 6 1/4 X 8 1/2 STRING STB. 6 1/4 X 30~ MONEL STEEL STRING STB. 6 1/4 X 30~ MONEL SERIAL NO. GLS-143 B-0519 GLS-778 B-0380 GLS-239 B-0375 053091 DRILL FIRM CEMENT F/10894 T/11026 (TOP OF FISH 11256) MWD SURVEY AND TIME/DRILL OFF PLUG. SAMPLES AT REPORT TIME INDICATE +- 10% CEMENT. FRESH WATER USED 200 CUMULATIVE 945 053191 DRILLING AROUND FISH W/ MUD MOTOR FRESH WATER USAGE 0 CUMULATIVE 945 060191 DRILLING WITH MUD MOTOR CHANGE OUT BHA, CDL, NUMEROUS TIGHT SPOTS ON TRIP OUT 10,581-10,182 10,124 RETRIEVE SURVEY AT HWDP. REAM MOTOR RUN F/11,026 T/11,248. REAMED GOOD, HOLE APPEARS TO BE IN GOOD CONDITION. DRILLING FRESH WATER USED 0 CUMULATIVE 945 060291 DRILLING T/11,548~. CBU AND SURVEY POH TO SHOE TO RECOVER SURVEY, TIGHT AT 11,062~ WORKING AT REPORT TIME FRESH WATER USED 25 CUMULATIVE 970 060391 TRIP FOR BHA CHANGE, RECOVER SURVEY, PICKUP 3 PT. STRING RMR. HOLE DEVELOPING KEYSEATS. NECESSARY TO UP REAM TO GET OUT OF HOLE. REAM ROLLER RMR THROUGH KEY SEAT AREAS 10,931 TO 11,150 DRILLING W/ BIT #8 FRESH WATER USED 15 CUMULATIVE 985 060491 DRILLING TO 11,849~ DROP SURVEY POH TO SHOE TO RECOVER SURVEY. WORK UP THROUGH KEYSEATS FROM 11,397 TO 11,244 USED TSA PIPE DRIVE ASSEMBLY TO DRILL UP. RETRIEVE SURVEY. RIH TO 9974~ (TOP KEYSEAT) REAM 9974~ TO 10,004~ AND 10,937~ TO 11,454~ AT REPORT TIME. FRESH WATER USED 15 CUMULATIVE 1,000 AOGCC\C21A23DR. DOC 060591 REAM AND WASH TO BOTTOM AFTER SURVEY C.B.U. PULL TO SHOE PUMP PILL POH, LAY DOWN 3 PT. RMR AND NB STB. TEST BOP~S AND ASSOCIATED WELL CONTROL EQUIPMENT M/U BHA AND RIH W/ BIT #9, CDL, LEDGES ON TRIP IN HOLE, NECESSARY TO REAM THROUGH LEDGES AT 10472, 10512, 11785. DRILLING FRESH WATER USED 0 CUMULATIVE 1000 060691 DRLG F/11928' T/12023' W/BIT #9. DROP DUAL SINGLE SHOT SURVEYS. RECOVER W/WIRELINE. DRLG F/12023' T/12242' W/BIT #9. PREP T/DROP SURVEYS AND POH. FRESH WATER USED: 40 BBLS CUMULATIVE: 1040 BBLS 060791 DROP DUAL SURVEY INSTRUMENTS. PULLED 2 STANDS DP. STRING BECAME STUCK. WORK STUCK STRING; BIT DEPTH AT 12004~. MIXED AND SPOTTED 41 BBL WEIGHTED PILL OF EMI-1267. PUT 4 BBLS OUTSIDE. PUMP 1 BBL EACH HOUR WHILE JARRING. EMI-1267 WAS IN PLACE 2.5 HRS AFTER BECOMING STUCK. CUM. FRESH WATER USED 1040 BBLS 060891 JAR ON STUCK STRING. BIT DEPTH 12004~. MOVE I BBL/HR EMI-1267 AROUND. CIRC/COND HOLE CLEAN. RETRIEVE SURVEYS W/WIRELINE. RIG UP DIA-LOG. FOUND FREE POINT AT 11743~. HELD SAFETY MEETING W/ALL HANDS. WORKED DOWN 10 ROUNDS OF LEFT HAND TORQUE. FIRED SHOT, NO BACK OFF. POH W/DIA-LOG. RELEASED TORQUE. MADE UP NEW SHOT/FREE POINT INDICATOR RUN IN HOLE W/SHOT #2. WORK PIPE/FREE POINT. FOUND FREE AT 11320'. (TOP OF HWDP). WORKED DOWN 12 RDS OF LH TORQUE. SHOT FIRED, GOT BACK OFF AT 11320~. POH, RIG DOWN DIA-LOG. POH, LAYED OUT SHOT JOINT. MADE UP MULE SHOE ON 3.5" CEMENTING TBG STINGER. TRIPPING IN HOLE AT RPT TIME. 060991 FINISHED TIH W/TBG STINGER. CIRC/COND F/CEMENT. PUMPED 5 BBLS FRESH WATER, TEST LINES T/2500 PSI, OK, PUMPED 35 BBLS MORE FRESH WATER. MIXED/PUMPED 226 SX CLASS "G" CEMENT +.30% CFR-3, + .17% HR-7. 41BBLS SLURRY, 16.7 PPG. USED 21.5 BBLS MIX WATER, 4.0 GAL SX, YIELD 1.02 CU FT/SX. FOLLOWED W/2 BBLS FRESH WATER. DISP W/192 BBL 9.6 PPG MUD. CIP AT 1110 HRS 06/08/91. NOTIFIED AOGCC VIA FAX OF PLUG. PULLED UP T/10839~, REVERSED OUT 1.5 PIPE VOL~S. POH T/SHOE. CDL 100~. FINISHED POH, LAYED DOWN 3.5" TBG STINGER. (15 JTS) TIH W/EXCESS 5" DP, POH LAYING DOWN SAME. (42 JTS) MAKE UP BHA ON BIT #10. SURFACE TEST MOTOR/MWD. TIH T/10948~. KELLY UP WASH/REAM F/10948~ T/11193~. AT RPT TIME, WORKING W/ANADRILL EQUIP TO CAPTURE SIGNAL. IADC BIT GRADING NOT PREVIOUSLY NOTED BIT #2: 3-3-WT-A-E-2-ER-HR BIT #3: 1-2-WT-A-E-2-CT-BHA BIT #4: 4-3-WT-A-E-1-ER-BHA BIT #5: LOST IN HOLE BIT ~6: 3-3-ER-A-E-2-SD-BHA AOG C C \C 21A23 DR. DOC BIT #7: 2-2-WT-A-E-1-RG-BHA BIT #8: 7-5-BT-A-E-2-CT-BHA BIT #9: LOST IN HOLE 061091 ANADRILL REPLACED SBT'S ON STD PIPE. CHANGE PULSATION DAMPNER ON PUMP. CLEAN OUT 10' OF RATTY CMT. ORIENT TOOLS. TIME DRLG OFF PLUG F/11203' T/11211' W/BIT #10. MWD LOST TOOL FACE. WORK ON UPPER/LOWER SBT'S. TIME DRLG OFF PLUG F/11211' T/11215' W/BIT #10. LATE REPORT: HELD TRIP DRILL W/EVE TOUR CREW 1640 HRS 06/08/91. 2 MINS RECIEVED VERBAL APPROVAL TO SIDE TRACK WELL FROM MR. LONNIE SMITH OF THE AOGCC AT 2000 HRS 06/09/91. BEGINING NEW FRESH WATER USAGE REPORT: DAILY 50 BBLS CUM 50 BBLS PREHYDRATED GEL ACCOUNTS FOR WATER USAGE. 061191 TIME DRILLING OFF PLUG F/11215' T/11232' W/BIT #10. MUD MOTOR AHEAD F/11232' T/11284' W/BIT #10 AT RPT TIME. DAILY WATER USED: 0 CUM WATER USED: 50 BBLS 061291 MUD MOTOR W/MWD F/11284' T/11338' W/BIT #10. STRING STUCK AT MOTOR/BIT, 11338'. HAD TORSIONAL MOVEMENT AT MWD BUT COULD NOT TURN STRING BELOW MWD. JAR/TORQUE ON STUCK STRING. RIG UP DIA-LOG. HELD SAFETY MEETING W/HANDS. BACKED OFF AT TOP OF MWD. TOF AT 11265'. RIG DOWN DIA-LOG. POH. LAYED DOWN SHOT MONEL DC. PICKED UP 15 JTS OF 3.5" TBG CEMENTING STINGER W/MULE SHOE. TIH AT REPORT TIME. DAILY WATER USED: 0 CUMULATIVE STARTS AGAIN: 0 1550 HRS 06/11/91 RECEIVED VERBAL APPROVAL FROM MR. LONNIE SMITH OF THE AOGCC TO POSTPONE BOPE TESTING AND LAY CEMENT PLUG AS NECESSARY. 061391 FINISHED TIH W/TBG CEMENTING STINGER, TAG TOF AT 11265' CIRC/COND F/CEMENT. CLEANED PIT FOR MIX WATER. FLUSHED ~INES F/CEMENT. PUMPED 5 BBLS FRESH WATER. TEST LINES T/2500 PSI.OK. PUMPED 35 BBLS AHEAD OF 632 SX CLASS "G" CEMENT + .30% CFR-3 + .17% HR-7. 4 GAL/SX 1.02 YIELD, 16.7 PPG 115 BBL SLURRY. 60 BBLS MIX WATER USED. 2 BBLS OF FRESH WATER BEHIND, DISPLACED W/189 BBLS 9.7 PPG MUD. CIP AT 1200 HRS PULLED 10 STDS DRILL PIPE. (ESTIMATED TOP OF CEMENT' 10900') REV OUT 1.5 DRILL PIPE VOL'S. PULLED OUT OF HOLE T/SHOE. LAYED DOWN EXCESS DP/DC'S FROM DERRICK. CDL 100'. FINISHED POH. LAYED DOWN TBG STINGER. (15 JTS) DID WEEKLY BOPE TEST. REPLACED SWIVEL PACKING. MAKE UP CLEAN OUT BHA. TIH CLEANING OUT BRIDGES/WORKING TIGHT HOLE 9997' AND 10509'. NO FRESH WATER USED. AOGC C \C 21A23DR. DOC 061491 CLEANING OUT BRIDGES F/10509' T/10760'. DRILLED OUT SAND BRIDGE FROM 10760' T/10798'. FINISHED REAMING OUT T/TOP OF CEMENT AT 10912'. POLISHED OFF PLUG F/10912~ T/10933~ (NOTE' SLM OUT OF HOLE CHANGED THE DEPTHS ABOVE TO 7~ DEEPER.) CIRC/COND FOR MOTOR/MWD. BTMS UP SAMPLE CONFIRMED CMT TOP. SLM OUT W/BIT #11. WORK TIGHT HOLE AT 10165' AND 9960'. LAY DOWN BHA. MAKE UP MOTOR/MWD ASSMY ON BIT #12. SURFACE TEST MWD. OK. TIH T/10875. REAM OUT UNDERGAGE HOLE F/10875~ T/10940' (BIT #11 WAS PINCHED) CIRC/WORK W/MWD ATTEMPTING T/OBTAIN SYNC ~IGNAL F/TOOL FACE/SURVEYS. BIT #10: LOST IN HOLE BIT #11COND:I-I-O-A-E-4-PB-BHA FRESH WATER USED: 40 BBLS CUMULATIVE USED: 40 BBLS 061591 WORKING TO GET MWD TOOL SIGNALS. DID NOT. POH. TIGHT HOLE AT 10230~, 10205~, 10175~, 9997~. CNG OUT MWD TOOL. CHECKED OUT MOTOR/BIT. (CHANGED OUT MWD SURFACE PACKAGE ALSO.) TIH. TEST RUN MOTOR/MWD AT 1ST JT HWDP, OK. FINISHED TIH. GOOD HOLE COND'S GOING IN HOLE. 5 PT SURVEYS. OK. ORIENT TOOLS, TIME DRILLING OFF PLUG W/BIT #12RR F/10940' T/10950~. WATER USED: 0 BBLS CUM USED: 40 BBLS BIT #12 COND: O-O-NO-A-E-I-NO-DTF 061691 MUD MOTORING F/10950~ T/11008~ W/MWD ON BIT #12RR. TIE IN SURVEY WAS 10892~. WATER USED: 100 BBLS (PREHYDRATE GEL FOR VIS CONTROL) CUM USED: 140 BBLS 061791 MUD MOTOR F/11008~ T/11089~ W/MWD ON BIT #12RR. CHECKED F/FLOW, NONE. POH. CHANGED BIT/BENT SUB. SURFACE TEST MWD, OK. TIH T/SHOE. CDL 100' FINISHED TIH. HOLE I~ GOOD COND. TRIPPING SLICK ASSMY. PRECAUTIONARY REAMED 106~ T/BOTTOM. ORIENT MOTOR, DRILL F/11089~ T/11094' W/MWD ON BIT #13. BIT #12RR COND: 2-2-A-SD-F-2-RG-HR. (ON 2 CONES, BEARINGS WERE GONE.) WATER USED: 0 CUM USED: 140 BBLS 061891 MUD MOTOR F/11094' T/11276' W/MWD ON BIT #13. CHECK F/FLOW, NONE. POH F/BHA AT REPORT TIME. SLICK ASSMY POH GOOD. WATER USED: 0 CUM USED: 140 BBLS 061991 FINISHED TRIP F/BHA AND NEW BIT #14. REAMED OUT MOTOR RUN F/10944~ T/11276' DRLG F/11276' T/11353' W/BIT #14. HIT ~HE "HC" COAL, MOMENTARILY STUCK BIT, WORKED LOOSE. CIRC/COND BOTTOMS UP. MUD LOGGER CONFIRMED "HC" COAL, EST TOP; 11348'. DRLG 1 FOOT T/11354'. (HAD 2' FILL ON BOTTOM) CIRC/COND AT RPT TIME. BIT #13 COND: 2-2-WT-A-E-1-NO-BHA WATER USED: 40 BBLS CUM USED: 180 BBLS AOGCC\C21A23DR. DOC 062091 DRILLING, MAKE I FOOT AND CIRC. 1 HOUR UNTIL COMPLETELY THROUGH COAL RIGHT ABOVE HC MARKER. PRESENTLY DRILLING, WORKING PIPE AND CIRC. UP ON ANY DRILLING BREAKS. FRESH WATER USAGE TODAY 10 CUMULATIVE 190 062191 DRILLING W/ BIT #14 TO 11,636 (UP REAM DRILLING DRILLING BREAKS) PULL THROUGH NUMEROUS TIGHT SPOTS TO SHOE, UP REAM THROUGH KEYSEATS. POH. TEST BOP~S PICKUP MUD MOTOR ASSEMBLY W/BIT #15, ORIENT AND RIH, (CDL) ORIENT MWD, SLIDING W/ BIT #15 TO 11,655 FRESH WATER USED: 0 CUMULATIVE: 190 BIT #14 I 0 D L B G 0 R 8 6 BT A E 1 SD HR 062291 DRILLING (SLIDING) WITH 3/4 DEGREE BENT HOUSING DRILEX. UNABLE TO MAINTAIN OR BUILD ANGLE. POH, STUCK W/ BIT AT 11,210~ WORK STUCK TOOLS ATTEMPT TO KNOCK DOWN (SUSPECT KEYSEAT) ROTATION AND UP JARRING ALSO UNSUCESSFUL. RIG UP DIA-LOG AND ASCERTAIN TOOLS FREE DOWN TO FILTER ABOVE MWD WORK IN REVERSE TORQUE AND BACK OFF ON TOP OF MWD. RIG DOWN DIA-LOG POH WITH STRING. FRESH WATER USED 40 CUMULATIVE 230 062391 POH LAY DOWN RECOVERED PART OF BHA (LEFT BIT, DRILEX, FS, XO, LC AND MWD IN HOLE MAKE UP CLEANOUT ASSEMBLY, AND RIH TO TOP OF FISH. CIRC AND COND ABOVE FISH FOR WASHPIPE POH W/ CLEANOUT ASSY. PICKUP 30~WASHPIPE ASSY. AND RIH. RUN IN WITH WASHPIPE BELOW CSG. SHOE, REAMING TO 10,187 TOO STICKY TO CONTINUE. POH LAY DOWN WASHPIPE JT. PICKUP SHORT WASHPIPE EXTENSION AND RIH. FRESH WATER USED 0 CUMULATIVE 230 062491 RIH WITH SHORTENED WASHPIPE ASSY. REAM AND WASH TO TOP OF FISH AT 11,134. ATTEMPT TO GET OVER FISH. TRIP, INSPECT WASHOVER SHOE, PICKUP NEW SHOE AND RIH WITH INCREASED LENGTH WASHPIPE (8.5~) MILL OVER FISH 11,134~ TO 11,141~ (7~) DULLED SHOE. POH, INSPECT SHOE AND WASHPIPE, INDICATIONS CONFIRM THAT WE CUT 7.25~ OVER FISH. REPLACE BURNING SHOE AND LENGTHEN WASHOVER PIPE TO 14.4~ MILLING OVER FISH WITH WASHPIPE ASSY. NO. 4 AT 0600 HRS. FRESH WATER USED 0 CUMULATIVE 230 062591 CUTTING OVER FISH WITH WASHPIPE TRIP, MAKEUP CONCAVE BOTTOM JUNK MILL AND RIH TO 11,139~ MILL AND SPUD DOWN ON FISH, 11,139 TO 11,154 POH WITH MILL, NO INDICATION OF MILLING ON IRON. APPEARED TO BE CUTTING FORMATION, MAKE UP BIT AND BOTTOM HOLE ASSY. WE WOULD BE ABLE AOGCC\C21A23DR. DOC TO DRILL WITH, AND RUN IN HOLE. BELIEVE FISH TO BE SIDETRACKED, WILL TRY TO MAKE BIT RUN AND REDRILL LOWER PORTION OF HOLE. (CDL) REAMING AND WASHING CAREFULLY TO BOTTOM IN ATTEMPT TO GET BY FISH. FRESH WATER USED 0 CUMULATIVE 230 062691 RIH WITH BHA TO DRILL (FISH BELIEVED TO BE SIDETRACKED) FISH APPARENTLY FELL DOWN HOLE. REAM OPEN HOLE, CONTACT TOP OF FISH AT 11,271~ TRIP OUT, PICKUP OVERSHOT AND WASHPIPE 14~ LONG (TO SWALLOW FISH PAST DAMAGED TOP) RIH. WORK DOWN ON FISH, INDICATIONS OF PICKUP NOT GOOD POH, WASHPIPE DID NOT GO OVER FISH. FISH LAYING IN LEDGE BELOW CENTER OF HOLE. SHORTEN FISHING ASSY. TO OVERSHOT ONLY. RIH WORK OVER FISH, INDICATIONS POSITIVE, OVERSHOT GOING OVER FISH. HOWEVER GRAPPLE WOULD NOT HOLD ON DAMAGED TOP PORTION OF FISH POH AT REPORT TIME. 062791 WORKING OVERSHOT OVER FISH AT 11,271~ (FISHING ASSY. CUT LIP GUIDE, OVERSHOT. FISHING TRIP #7) POH, NO RECOVERY, INDICATIONS ARE WE WERE OVER FISH BUT GRAPPLE WOULD NOT HOLD BECAUSE OF DAMAGE TO TOP OF FISH. MAKE UP FISHING ASSY. #8 WALL HOOK,-O/S BOWL,-WP EXT 13.5~-TOP SUB 2 DEGREE BENT SUB-JARS ATTEMPT TO WORK OVER FISH, INDICATIONS IN HOLE INCONCLUSIVE. POH, NO RECOVERY, MARKS ON TOOLS INDICATE WE CONTACTED FISH WITH LEADING EDGE OF WALL HOOK BUT FAILED TO SWALLOW IT. BEND JOINT OF DRILL PIPE AND MAKE UP OVERSHOT WITH WALL HOOK AND 6~EXTENSION SUB, TOP SUB, JARS. RIH ATTEMPT TO WORK OVER TOP OF FISH, POH AT REPORT TIME W/ FISHING ASSY. NO. 10 FRESH WATER USED 40, CUMULATIVE 270 062891 POH WITH WALL HOOK AND OVERSHOT, NO RECOVERY, NO INDICATION OF CONTACT WITH TOP OF FISH. MAKEUP BIT AND BHA, RIH TO CLEAN OUT TO TOP OF FISH DID NOT TOUCH FISH, APPARENTLY SIDETRACKED DRILLING TO 11,285~ NO SIGN OF FISH. POH TO LAY KICKOFF PLUG. TEST BOP, 13 5/8 5000 FLANGE BETWEEN DSA ON AP SPOOL AND RISER SPACER LEAKED. INSTALL AND LOCKDOWN TEST PLUG, PICKUP BOP STACK AND REPLACE BX160 RING. DID NOT TEST. WILL REPLACE DSA AFTER LAYING K.O. PLUG TRIP IN HOLE WITH 3 1/2" TUBING STINGER TO LAY PLUG. NOTE: RECEIVED VERBAL APPROVAL FROM LONNIE SMITH AOGCC TO PLUG AND SIDETRACK. 06/27/91 FRESH WATER USED 40 CUMULATIVE 310 062991 RIH W/ DRILL PIPE AND 3 1/2" X 463~ TUBING STINGER TO LAY KICKOFF PLUG WITH MULE SHOE AT 11,285~ CIRC. AND COND. FOR PLUG. MAKE UP CMT. LINES PUMP 5 BBLS. WATER, TEST LINES AND PUMP ADDITIONAL 35 BBLS. WATER. MIX 296 SX. DENSIFIED CMT. 16.7 PPG. (54 BBLS.) 0.3% CFR2 & .17% HR7 FOLLOW W/ 2 BBLS. WATER AND 192 BBLS. MUD. PIPE PULLED DRY. ?OH TO SHOE AND CIRC. BOTTOMS UP. AOGCC\C21A23DR. DOC POH, PICKUP HOWCO SSC PACKER (HURRICANE PKR) AND SET IN CSG. AT 566~ RELEASE FROM PKR. AND LAY DOWN 18 JTS. DRILL PIPE. WITH WELL SECURE, PICKUP BOP STACK AND REPLACE DOUBLE STUD ADAPTER FROM AP SPOOL TO RISER. NIPPLE UP STACK AND RETEST. LOW AND HIGH PRESSURE TEST HELD GOOD. RIH UNSEAT PACKER AND POH, LAY DOWN 15 JTS. 3 1/2 TUBING AND FISHING TOOLS IN DERRICK. RIH WITH CLEANOUT ASSY. TO TAG AND DRESS CMT. PLUG FOR KICKOFF. TAG CEMENT AT 11,153~ DRESS PLUG TO 11,163~ CMT. HARD. LOOKS LIKE GOOD PLUG. 063091 TRIP OUT WITH CLEAN OUT ASSY. PICKUP DRILEX MOTOR AND KICKOFF ASSY. RIH. HOLE IN GOOD CONDITION NO TIGHT SPOTS RUN 5PT. SURVEY WITH MWD DRILLING OFF PLUG. 11,163~ TO 11,179~ NAVIGATIONALLY DRILLING W/ MUD MOTOR FRESH WATER USED 150 CUMULATIVE 500 NOTE: USED BIT #13RR FOR CLEAN OUT TRIP PRIOR TO KICKOFF ASSY. 070191 DRILLING W/ MUD MOTOR, KICKING OFF PLUG. HIGH PH AND CMT. IN SAMPLES INDICATE CLOSE TO PLUG. WHILE DRILLING MOTOR LOCKED UP AT 11,271 (TOP OF FISH) POH, BIT HAD POSITIVE INDICATION OF CONTACT WITH FISH, STAND BACK DRILEX ASSY. AND PICKUP 3 1/2 TUBING STINGER. RIH TO 11,271 TO LAY PLUG. CIRC. AND COND. FOR PLUG. MXG. AND SPOTTING CMT. PLUG. DETAILS OF PLUG NEXT REPORT. CALCULATED TOP OF PLUG 11,000. FRESH WATER USED 40 BBLS CUMULATIVE 540 BBLS 070291 HOWCO PUMPED 40 BBLS. WATER FOLLOWED BY 420 SX PREMIUM CMT. BLENDED WITH .3% CFR2 AND .17% HR7 16.7 PPG. DISPLACED WITH 2 BBLS. WATER AND 191BBLS. MUD. PIPE PULLED DRY. REVERSE OUT DRILL PIPE AT CSG SHOE. POH, LAY DOWN EXCESS DRILL PIPE. RIG UP DIA-LOG, RUN CSG. CALIPER IN 9 5/8" FROM 9249~ TO SURFACE. RIH W/ CLEAN OUT ASSY. TAG TOP OF PLUG AT 10,999~ DRESS PLUG TO 10,033~. POH FOR DRILEX AND MWD FOR KICKOFF. FRESH WATER USED 5 BBLS. CUMULATIVE 545 BBLS. 070391 PICKUP DRILEX MUD MOTOR ASSY. AND RIH TO KICK OFF PLUG. ORIENT AND RUN 5 PT. SURVEY, TIME DRILL OFF PLUG. DRILLING W/ MUD MOTOR FRESH WATER USED TODAY 110 CUMULATIVE 655 BBLS. 070491 DRLG F/11110~ T/11273~ W/MUD MOTOR/MWD ON BIT #19. FRESH WATER USED: 187 BBLS CUM USED: 842 BBLS AOGCC \C 21A23 DR. DOC 070591 DRLG F/11273' T/11310' W/MUD MOTOR/MWD ON BIT #19. POH FOR BHA. LAYED DOWN MOTOR/MWD. WEEKLY TESTING OF BOPE. ANNULAR PREVENTER PACKING UNIT LEAKED. REPLACED ANNULAR PACKING UNIT. FINISHED TESTING BOPE. OK. MAKE UP ROTARY ASSMY ON BIT #18RR. TIH AT RPT TIME. (CLEANED CMT FROM HWDP AND BOTTOM 7 STDS OF DRILL PIPE.) BIT #19 COND: 2-2-WT-A-E-I-SD-BHA FRESH WATER USED: 200 BBLS CUM USED: 1042 BBLS HELD TRIP DRILL W/EVE TOUR AND THEN THE MORN TOUR DRLG CREWS. 070691 CDL 100'. FINISHED TRIP IN HOLE TO TOP OF MOTOR RUN AT 11033'. REAM OUT MOTOR RUN F/11033' T/11310' W/BIT #18RR. DRLG F/11310' T/11367', TOP OF UPPER "HC" COAL. DRLG/WORK THRU COAL T/11372'. DRLG F/11372' T/11397' T/TOP OF LOWER "NC" COAL. DRLG/WORKING THRU COAL AT RPT TIME. EST BOTTOM AT 11400'/11401~. WATER USED: 25 BBLS CUM USED: 1067 BBLS. 070791 DRLG/WORK COAL F/11401' T/11404' W/BIT #18RR. CIRC/COND MUD F/LOGS. DROP DUAL SINGLE SHOT SURVEYS. SLM OUT OF HOLE, NO CORRECTION. HOLE IN GOOD COND. RIG UP DIA-LOG. RAN CASING CALIPER. CSG OK TO SET LINER TOP @ 8750~. RIG DOWN DIA-LOG. RIG UP W-A. LOGGING MLL-DLL-GR AT RPT TIME. LOGGERS TD AT 11375~. BIT #18RR COND: 3-3-JD-MH-E-I-SD-TD WATER USED: 50 BBLS CUM USED: 1117 BBLS 070891 FINISHED LOGGING MLL-DLL-GR. RAN ACOUSTIC-GR. ACOUSTIC FAILED. POH, CHANGED AC POWER BLOCK IN TOOL. FINISHED LOGGING. RIG DOWN. TIH W/BIT #18RR, RUNNING RABBIT THRU 95 STDS. FILLED DP AT SHOE. WAS NOT ABLE TO CIRC. POH. FOUND BIT PLUGGED W/CEMENT PIECES. CLEANED OUT BIT/FLOAT. TIH T/SHOE. CIRC OK. CDL 100~. FINISH TIH. PRECAUTIONARY REAM THRU "HC" COALS AT RPT TIME. CUM WATER USED: 1117 BBLS TOTAL. 070991 DRLG F/11404' T/11410' W/BIT #18RR. CIRC/COND F/LINER. POH LAYING DOWN BAD DRILL PIPE. (300 JTS) PICKED UP NEW, NEVER USED DP POH STANDING BACK NEW DP AT RPT TIME. NOTE: DP LAYED DOWN HAD RESIDUAL CEMENT INSIDE THAT KEPT BREAKING OFF. 071091 FINISHED POH, STAND BACK NEW 5" DRILL PIPE. HELD PREJOB SAFETY MEETING RIG/RAN 7" LINER, DETAILED: TIW SHOE AT 11410', FC AT 11362~ LDG COL AT 11279'. TURBOLIZERS INSTALLED ON BTM 6 JTS AND 3 IN LINER LAP. RAN TOTAL OF 63 JTS, 26# L-80 LT&C R-3. TORQUE T/3400#. TOL AT 8725~. CIRC/COND AT SHOE. TIH, TAGGED UP ON LEDGE AT 11364~ INSTALLED HEAD PIN, WASH/WORK DOWN. CIRC/COND F/CEMENT AT 11410~. RECiP PIPE 7~ STKS, SHOE BELOW "HC" COAL AOGCC\C21A23DR. DOC PUMP 5 BBLS FRESH WATER, TEST LINES T/5000#. OK. PUMPED 45 BBLS WATER AHEAD OF 2575 SX "G" CMT + .40% HALAD 344 + .27% HR-7. 555 BBLS SLURRY 328 BBLS MIX WATER, 5.35 GAL/SX, YIELD 1.20 CU/FT/SX.15.5 PPG. DROPPED TIW DP PLUG, PUMPED 10 BBLS WATER, 145 BBLS MUD. LINER WIPER PLUG SHEARED AT 2200 PSI. PUMPED ADDITIONAL 100 BBLS 9.8 PPG MUD T/BUMP. PRESSURED UP T/3500#, SET HANGER. ROTATED 36 TURNS, RELEASED F/HANGER. PULLED OUT OF HANGER W/RUNNING TOOL. HAD 1200 PSI DIFFERENTIAL PRESS. LET WELL U-TUBE 15 MINS UNTIL EQUALIZED. PULLED 12 STANDS DRILL PIPE. REVERSE CIRC 6000 STKS. (3 DP VOLS) TO CLEAN INSIDE OF DP GOOD. EST 28 BBLS CMT RETURNS. HAD GOOD RETURNS THRU OUT CEMENT JOB. POH W/LINER RUNNING TOOL AT REPORT TIME. NOTE: RECIPED PIPE UNTIL CMT GOT AROUND SHOE THEN CSG STUCK ON BOTTOM. 071191 FINISHED POH, LAYED DOWN LINER RUNNING TOOL.TIH W/8.5" CLEAN OUT ASSMY TAGGED CEMENT AT 7327'. LAY DOWN EXCESS DP FROM DERRICK. DISPLACED HOLE W/INLET WATER TO DRILL OUT CEMENT. STORED 460 BBLS MUD. DRLG CMT F/7327' T/7677' W/BIT #18RR. HAD PLATFORM AC POWER FAILURE. (CAUSED BY #5 DC GEN~S BLOWER MOTOR WENT BAD.) DRILL CMT F/7677' T/7810~ W/BIT #18RR. HAD 500+ UNITS OF GAS IN RETURNS. CHECKED F/FLOW, NONE. NO GAS BUBBLES SEEN IN WELL BORE. SHUT DOWN PUMP. PUT HOSE FEEDING INLET WATER TO PIT FROM WATER FLOOD DEPT IN POSSUM BELLY. HAD GAS FROM SOURCE WATER 02 TOWER. CHANGED TO DIFFERENT WATER SUPPLY, UP STREAM OF THE 02 TOWER. (THE 02 TOWER STRIPS OXYGEN FROM INLET WATER PRIOR TO INJECTION USING GAS AS THE STRIPPING MEDIUM. SOME RESIDUAL GAS, 500+ UNITS, REMAINS ENTRAINED.) DRILL CMT F/7810' T/8725', TOP OF LINER, W/BIT #18RR. CIRC HOLE CLEAN. TEST LINER LAP/CSG T/3700 PSI F/30 MINS. OK. 071291 POH, LAYED DOWN 29 JTS 5" DP, 17 HWDP, 3 6.25" DC'S, BIT. CHANGED PIPE RAMS TO 3.5" BY 5" VARIABLES. DID WEEKLY BOPE TEST. OK. MAKE UP NEW BIT/BHA, PICKED UP 100 JTS OF 3.5" 15.50# DRILL PIPE, TIH TO TOP OF LINER AT 8725'. CLEANED OUT LINER F/8725' T/8938~ W/BIT #20. CDL 100'. TIH F/8938' T/11201'. TAGGED CMT ABOVE LDG COLLAR. DRLG CMT F/11201' T/l1279'/DRLG ON FLOAT EQUIP. PREP T/TEST LINER. BIT #18RR COND:4-4-JD-MH-E-I-LT-BHA 071391 DRLG OUT PLUGS/LDG COLLAR AT 11279' W/INLET WATER. TEST LINER T/3200 PSI F/30 MINS. OK. DRLG OUT CEMENT F/11279' T/11383' W/INLET WATER. DISPLACE INLET WATER W/450 BBLS OF "OLD" MUD BLENDED W/450 BBLS "NEW" MUD. CIRC/COND F/DRILL OUT INTO HEMLOCK. DRILLED F/11383' T/11413'; 3' BELOW SHOE. PERFORMED FORMATION LEAK-OFF TEST W/9.6 PPG MUD. WENT T/2925 PSI, NO LEAK-OFF. TEST WAS EMW 15.7 PPG AT 9200' TVD. DRLG F/11413' T/11595' W/BIT #20 AT REPORT TIME. AOGCC\C21A23DR. DOC 071491 DRLG F/11595' T/11649' W/BIT #20. DROPPED DUAL SINGLE SHOT SURVEY INSTRUMENTS. PULLED 10 STDS. HOLE DID NOT TAKE PROPER AMT OF MUD, CHECKED F/FLOW, HAD SMALL FLOW. TIH. CIRC/COND, INCREASED MUD WEIGHT F/9.5PPG T/9.7PPG. WELL DEAD. SLM OUT F/NEW BIT. (NO CORRECTION) CNG BIT/BHA. TIH. DRLG F/11649' T/11715' W/BIT #21. BIT #20 COND: 2-2-BT-H-E-1-NO-HR 071591 DRLG F/11715' T/11877' W/BIT #21. CHECK F/FLOW, NONE. DROP DUAL SINGLE SHOT SURVEY INSTRUMENTS. POH T/LAST JT OF 5". RETRIEVE SURVEYS. FINISH POH. LAYED DOWN MONEL COMPONENTS OF BHA, REPLACED W/STEEL. MAKE UP NEW BIT, TIH T/SHOE. CDL 100'. FINISHED TIH T/11827'. REAMED F/11827' T/11877'. DRLG F/11877' T/11920' W/BIT #22. BIT #21COND: 3-7-BT-MH-E-1-CT-HR 071691 DRLG F/11920' T/12063' W/BIT #22. CHECK F.FLOW, NONE. DROP DUAL SINGLE SHOT INSTRUMENTS. (F/ANGLE INFO) POH. LAYED DOWN 1 STEEL DRILL COLLAR. MAKEUP NEW BIT, TIH. DRLG F/12063' T/12110' W/BIT #23. BIT #22 COND: 8-6-BT-A-E-I-CT-TQ/HR ANGLE AT 12048' WAS 55.0 DEGREES. 071791 DRLG F/12110' T/12193' W/BIT #23. CHECK F/FLOW, NONE. POH, CNG BIT, TIH T/SHOE, CDL 100', FINISH TIH. DRLG F/12193' T/12290' W/BIT #24. CIRC/COND FOR LOGS AT 12290'. BIT #23 COND' 5-6-BT-MH-E-1-WT-PR 071891 POH (SLM) FOR LOGGING RIG UP ATLAS, PU DLL-ACOU-GR, TOOL PROBLEM AT 9700' POH (TELEMETRY SUB BAD) RIH. TOOLS STOPPED AT 11,455' POH. REMOVE ACOUSTIC AND ALL STANDOFFS. RIH TO TD LOG TO CSG AND REPEAT. POH PICKUP ACOUSTIC W/ CUT DOWN CENTRILIZER FINS. STOP AND GO IN HOLE. LOG TO CSG AND REPEAT. RIG DOWN ATLAS. RIH W/RR BIT #20 FOR CLEAN OUT AND COND. TRIP CIRC. AND COND. MUD AND HOLE FOR 5" LINER NO FRESH WATER USED TODAY, CUMULATIVE 1437 BBLS. 071991 C&C MUD IN PREPARATION TO RUN LINER. PUMP PILL, POOH TO RUN LINER RIG UP TO RUN LINER. RIH W/5" LINER AS DETAILED: JOINTS LENGTH DESCRIPTION FROM TO 15.13 TIW TC HYDRO HANGER & LG-6 SLEEVE 11205.54 11220.67 0.77 5" 18# FSJ X 5" 18# FL4S X-OVER 11220.67 11221.44 26 1025.26 5" 18# N-80 FL4S CASING 11221.44 12246.70 1.00 TIW HS-SR LANDING COLLAR 12246.70 12247.70 1 38.55 5" 18# N-80 FL4S CASING 12247.70 12286.25 1.55 TIW CL SINGLE VALVE FLOAT COLLAR 12286.25 12287.80 2.20 TIW CLS-2 DOUBLE VALVE FLOAT SHOE 12287.80 12290.00 27 1084.46 AOGCC\C21A23DR. DOC NOTE: 5 MILAM TURBOLIZERS (FROM DSR) RUN IN LINER LAP RUN LINER TO 7" LINER SHOE ON 3-1/2" & 5" DRILL PIPE MU CEMENT MANIFOLD ON JT OF 5" DP & CIRCULATE DP VOLUME RIH WITH LINER TO TD - NO HOLE PROBLEMS EXPERIENCED C&C MUD IN PREPARATION FOR CEMENT JOB WHILE RECIPROCATING LINER CEMENTED LINER W/300 SX CLASS "G" + 0.4% HALAD-344 + 0.2% HR-7 + 0.2% CFR-3 (NF-1DEFOAMER ADDED TO MIX WATER). SLURRY PROPERTIES: 15.8 PPG, 5.35 GAL/SK, 1.20 CF/SK. 30 BBL FIW SPACER PRECEDING CEMENT (PUMPED 5 BBL, TESTED LINES TO 3500 PSI, THEN PUMPED 25 BBL). 10 BBL FIW FOLLOWED CEMENT. DISPLACED WITH 174 BBL 9.7 PPG MUD AT AN AVERAGE RATE OF 6 BPM. BUMPED PLUG WITH 3500 PSI AT 0400 HRS 7/19/91. LINER STUCK ON BOTTOM JUST BEFORE PUMPING CEMENT. LINER WIPER SHEAR WAS NOT SEEN. BUMPED PLUG 4 BBL BEFORE THEORETICAL DISPLACEMENT. RELEASE FROM LINER. EVIDENCE OF CEMENT ABOVE TOL. POOH 20 STANDS AND REVERSE CIRCULATE. 072091 LAY DOWN T.I.W. CEMENTING HEAD. POH 20 STANDS AND REVERSE OUT CMT. POH LAY DOWN SETTING TOOL AND CEMENTING HEAD. TEST CHOKE MANIFOLD, BOP, AND ALL RELATED SURFACE WELL CONTROL EQUIP AS PRESCRIBED, SENT COPY OF STATE OF AK. REPORT TO AOGCC. PICKUP CLEANOUT ASSEMBLY W/ RR20 BIT, RIH, TAG TOP OF LINER AT 11,20~ (NO CMT. ABOVE LINER TOP. BACK PRESSURE WHEN PULLING RETRIEVABLE PACKOFF BUSHING OUT OF LINER TO INDICATED IN EXCESS OF 100~ CMT. ABOVE LINER TOP. (ASSUME CMT. FELL DOWN IN 5" LINER.) CLOSE BOP AND TEST LINER AND LAP TO 3,700 PSI FOR 30 MIN. PRESSURE INTEGRITY CONFIRMED. POH LAY DOWN BHA (CDL) PICKUP 3-1/8" DRILL COLLARS AND 4-1/8" MILL ON 2-7/8 PAC DRILL PIPE. RIH TAG CMT AT 11,398. APPROX. 888~ CMT IN 5" LINER. CLEAN OUT CMT. 072191 TAG CMT IN 5" LINER AT 11,398~. LAY DOWN 30 JTS. OF 5" DRILL PIPE TO CLEAN OUT CMT. DRILL AND WASH FIRM CMT OUT OF 5" LINER. DRILL LANDING COLLAR AND STOP AT FLOAT COLLAR. (12,286) POH WITH MILL AND CLEANOUT ASSEMBLY. PICKUP 5" CSG SCRAPER AND RIH. 072291 RIH WITH 5" CASING SCRAPER TO 12,286~ CBU POH LAY DOWN 3 1/2 HEAVY WALL DRILL PIPE AND 4 3/4 BHA, LAY DOWN EXCESS 5" DRILL PIPE. PICKUP 2-7/8 PAC STINGER AND 7" AND 9 5/8" CASING SCRAPERS SPACED OUT TO RESPECTIVE LINER TOPS. RIH CBU REVERSE CIRCULATE OUT DRILLING MUD W/ FILTERED INLET WATER. CIRCULATE AND CLEAN UP FIW. FILLING DECK TANKS AND RESERVE TANK WITH 1 MICRON FIW FOR SWEEP AND FINAL CIRCULATION. (PICKING UP 2-7/8" TUBING AND STANDING BACK IN DERRICK WHILE WORKING ON COMPLETION FLUID) 072391 CIRC FILTERED INLET WATER REVERSE CIRC X-C POLYMER HI VIS SWEEP FOLLOWED BY 1 MICRON FIW CLEAN AND FLUSH CHOKE MANIFOLD, TRIP TANK AND FILLUP LINE. POH W/ TANDEM CASING SCRAPER ASSEMBLY. PICKUP HALIBURTON RESERVOIR AOGCC\C21A23DR. DOC SERVICES TEST HEAD ON 5" DRILL PIPE. HELD SAFETY METTING WITH ALL SERVICE COMPANY AND RIG CREWMEMBERS REGARDING HANDLING OF PERFORATING GUNS. PICKUP PERFORATING ASSEMBLY AS PER VANNSYSTEM INSTALLATION DIAGRAM.(copy on fax) FILL 3 1/2" DRILL PIPE 3115' ABOVE MULTI SERVICE VALVE FOR CUSHION. RIH WITH PERFORATING ASSEMBLY. 072491 RIH W/ PERFORATING TEST STRING ASSEMBLY. RIG UP DRESSER ATLAS, RUN GR IN DRILL STRING AND REPOSITION STRING SO AS TO HAVE PERFORATIONS ON DEPTH WITH DUAL LATERLOG GAMMA RAY DATED 17-07-91. TEST HALIBURTON RESERVOIR SERVICES CONTROL HEAD AND TEST MANIFOLD TO 2,000 PSI. SHOOT FLUID LEVEL AND VERIFY HEIGHT OF FIW CUSHION. HAVE SAFETY MEETING, DISCUSS SEQUENCE OF OPERATIONS AND ALTERNATE PROCEDURES IN CASE OF PACKER FAILURE AND OTHER OPTIONS IN CASE OF OPERATION ANNOMALY. PRESSURE ANNULUS AND OPEN MULTI-SERVICE VALVE, SLOWLY BRING ANNULUS PRESSURE OP TO 2400 PSI. POSITIVE INDICATION OF GUNS FIRING AT 2200 PSI. MONITOR FLUID LEVEL IN DRILL PIPE FOR 2 HRS ANNULUS STATIC. CYCLE OMNI VALVE INTO REVERSE POSITION, REVERSE OUT OIL AND WATER. OPEN BYPASS AND UNSEAT PACKER, REVERSE OUT WELL TO PRODUCTION UNTIL CLEAN. CHECK WELL STATIC. RIG DOWN TEST HEAD AND MANIFOLD. POH, LAY DOWN DRILL PIPE AND GUN/TEST STRING. PERFORATED FOLLOWING INTERVALS' HC-HD HD-HEHE_HF HI-HE HN-HR HR-HZ PERFORATED WITH VANN SYSTEMS 3 3/8" SCALLOPED GUNS, 4 SHOTS PER FOOT WITH 32 GR. D.P. CHARGES. NINETY DEGREE PHASING. 11415-11460 11490-11508 11564-11636 11734-11764 11786-11990 12008-12108 and 12140-12176 12208-12280 072591 POH LAY DOWN DRILL PIPE WORK STRING AND PERF /TEST STRING. LAY DOWN 2 7/8" PAC DRILL PIPE AND 3-1/16" DRILL COLLARS. PULL WEAR BUSHING, CHANGE TO 2 7/8" PIPE RAMS AND TEST. PICKUP 2 7/8" TUBING COMPLETION STRING (details on next page) AND RIH LAND TUBING W/ BAKER SHEAR OUT SUB AT 11,198' RIG UP SLICKLINE, TEST TUBING TO 3,000 PSI FOR 30 MIN. AND SET PACKER. SHEAR OUT BALL ON BAKER WIRELINE ENTRY GUIDE W/ 3,500 PSI. PICKUP TUBING STRING AND CHECK PACKER SET. RIH WITH SLICKLINE AND RETRIEVE BALL VALVE DUMMY AND MAKE DRIFT RUN TO 11,300' RIG DOWN SLICKLINE. INSTALL BACK PRESSURE VALVE AND REMOVE BOP AND RISER. COMPLETION DETAIL: 2 7/8" 8RD AMD AB MOD TUBING DESCRIPTION DEPTH (TOP) TUBING HANGER 34.70 OTIS "XXO" SSSV 326.87 GLM #1 1839.41 GLM #2 3677.43 GLM #3 5454.46 AOGCC \C 21A23DR. DOC GLM #4 6980.05 GLM #5 8124.15 GLM #6 9002.52 GLM #7 9666.95 GLM #8 10396.43 GLM #9 11063.65 OTIS DX SLEEVE 11109.05 BAKER "SB-3" PACKER 11145.02 OTIS "XN" NIPPLE 11186.83 BAKER WIRELINE ENTRY GUIDE 11198.89 UP WEIGHT PRIOR TO LANDING 95,000 DOWN WEIGHT 72,000 INSTALL TWO WAY CHECK AND REMOVE AND LAY DOWN RISER. REMOVE AND REDRESS TUBING HANGER LOCKING SCREWS AND REPLACE PACKING. INSTALL TREE. REMOVE BPV AND RIG UP SHELL WIRELINE. TEST LUBRICATOR. SET OTIS SSSV AND TEST. RIG DOWN LUBRICATOR. PREPARE TO SKID RIG. LOOSEN STORM CLAMPS. RIG DOWN CHOKE LINES, FLOW LINES, STAIRS. CHANGE HATCH COVERS TO ACCOMODATE RIG ON NEXT WELL. RELEASE RIG FROM C21A-23 AT 1400 HRS. 07/25/91. TEST TREE TO 5000 PSI. AOGCC\C21A23DR. DOC SHELL WESTERN E & P, INC. C21A-23 REVISED 8/29/9~ GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY SHELL WESTERN E & P, INC. COMPANY C21A-23 WELL NAME COOK INLET LOCATION AL591D22 MWD 08/29/91 JOB NUMBER KEVIN DESORMEAUX TYPE SURVEY DIRECTIONAL SUPERVISOR NAME TITLE pATE GNATURE 100 FT. 12290 FT. DEPTH INTERVAL FROM TO 05/11/91 07/06/91 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. 08/29/91 3REAT LAND DIRECTIONAL DRILLING, INC. 21ient .... : SHELL WESTERN E&P, ?ield ..... : PLATFORM C qell ...... : C21A-23 ~ection at: 41.96 Engineer.. : KEVIN DESORMEAUX INC. Computation...: RADIUS OF CURVATURE Survey Date...:' 08/29/91 RKB Elevation.: 105.00 ft Reference ..... : RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 100 0.15 200 0.18 265 0.25 295 0.42 325 0.28 VERTICAL-DEPTHS BKB SUB-SEA **** Original 100.0 -5.0 200.0 95.0 265.0 160.0 295.0 190.0 325.0 220.0 SECTION DISTNCE hole' (C1 0.1 0.3 0.6 0.7 0.8 DIRECTION AZIMUTH 1-23) RELATIVE-COORDINATES FROM-WELL-HEAD 100 MD to 9178 MD **** 84.66 0.0 N 0.]. E 346.71 0.2 N 0.3 E 46.31 0.4 N 0.3 E 95.54 0.5 N 0.5 E 69.35 0.5 N 0.7 E CLOSURE DL DISTNCE AZIMUTI! /100 0.1 84.66 0.]5 0.4 51.. 88 O. 03 0.6 37.95 O. 11 0.7 45.45 0.57 0.9 52.74 0.47 356 0.19 386 0.16 416 0.30 446 0.62 478 0.89 356.0 251.0 386.0 281.0 416.0 311.0 446.0 341.0 478.0 373.0 1.0 47.97 0.6 N 0.8 E 1.0 319.26 0.7 N 0.8 E 1.0 284.82 0.7 N 0.7 E 0.9 277.3]. 0.8 N 0.5 E 0.7 279.21 0.8 N 0.0 E 1.0 53.50 0.29 1.0 50.02 0.10 1.0 43.62 0.47 0.9 30.67 1.07 0.8 3.05 0.84 509 0.97 539 1.07 571 1.59 651 2.23 680 3.28 509.0 404.0 0.4 539.0 434.0 0.1 571.0 466.0 -0.4 650.9 545.9 -1.9 679.9 574.9 -2.4 277.81 0.9 N 0.5 W 274.51 1.0 N 1.0 W 276.04 1.0 N 1.7 W 280.25 1.4 N 4.4 W 302.25 1.9 N 5.7 W 1.0 333.65 0.26 1.4 314.64 0.33 2.0 301.10 1_.63 4.6 288.00 0.80 6.0 288.75 3.63 696 3.21 722 3.06 786 2.87 817 2.95 847 3.19 695.9 590.9 -2.5 721.8 616.8 -2.8 785.7 680.7 -3.5 816.7 711.7 -3.8 846.7 741.7 -4.2 301.18 2.4 N 6.4 W 300.61 3.1 N 7.6 W 300.11 4.8 N 10.5 W 297.58 5.6 N 11.9 W 295.35 6.3 N 13.3 W 6.9 290.45 0.44 8.3 292.24 0.58 11.5 294.56 0.30 13.1 295.07 0.26 14.7 295.23 0.80 878 3.55 877.6 ~urvey Codes: 7/GYRO 221A23D B1.22) 772.6 -4.8 292.38 7.0 N 15.0 W 16.5 295.08 1.16 C21A-23 MEAS INCLN DEPTH ANGLE 909 3.91 939 4.52 969 5.02 1028 6.10 1090 7.16 7 1121 7.36 7 1208 7.08 7 1270 6.76 7 1314 6.59 3 1507 8.79 3 1596 9.84 3 1690 10.95 3 1781 12.20 3 1874 13.76 3 1962 15.33 2054 17.00 2146 19.00 2268 21.90 2359 23.90 2451 26.00 2542 27.80 2630 29.90 2724 32.10 2817 34.80 2909 37.26 2921 37.70 VERTICAL-DEPTHS BKB SUB-SEA 908.5 803.5 938.5 833.5 968.4 863.4 1027.1 922.1 1088.7 983.7 1119.4 1014.4 1205.7 1100.7 1267.3 1162.3 1311.0 1206.0 1502.2 1397.2 1590.1 1485.1 1682.5 1577.5 1771.7 1666.7 1862.3 1757.3 1947.5 1842.5 2035.8 1930.8 2123.3 2018.3 2237.6 2132.6 2321.4 2216.4 2404.8 2299.8 2486.0 2381.0 2563.1 2458.1 2643.6 2538.6 2721.2 2616.2 2795.6 2690.6 2805.1 2700.1 'Survey Codes: 3/MWD 7/GYRO RECORD OF SURVEY SECTION DISTNCE -5.5 -6.4 -7.5 -10.2 -13.9 -15.9 -21.8 -26.2 -29.3 -42.4 -47.9 -54.1 -60.4 -67.0 -73.3 -80.1 -87.2 -97.4 -105.3 -113.2 -120.9 -128.5 -136.0 -143.4 -150.9 DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD 288.69 7.7 N 16.9 W 287.68 8.4 N 19.0 W 285.22 9.1 N 21.4 W 281.47 10.4 N 26.9 W 280.98 11.8 N 33.9 W Page 2 CLOSURE DISTNCE AZIMUTt! 18.6 294.58 20.7 293.90 23.2 293.11 28.9 29]. ].8 35.9 289.21 281.33 12.6 N 37.8 W 39.8 288.42 277.11 14.3 N 48.6 W 50.6 286.44 275.01 15.1 N 56.0 W 58.0 285.]] 274.67 15.6 N 61.1 W 63.0 284.28 287.90 20.6 N 86.4 W 88.8 283.41 291.00 25.4 N 99.9 W 103.1 284.26 290.70 31.4 N 115.8 W 120.0 285.]_9 292.70 38.2 N 132.8 W 138.1 286.04 294.30 46.5 N 151.9 W 158.9 287.02 296.20 55.9 N 171.9 W 180.8 288.02 67.5 N 194.8 W 206.1 289.10 80.5 N 220.0 W 234.3 290.11 100.6 N 257.6 W 276.6 291.34 117.8 N 288.6 W 311.7 292.21 137.4 N 322.1 W 350.2 293.10 297.30 297.50 298.70 299.40 301.10 301.20 302.30 303.60 303.80 304.10 08/29/9]. 158.7 N 357.3 W 391.0 293.94 181.0 N 393.4 W 433.1 294.71 207.3 N 434.0 W 481.0 295.53 235.8 N 476.7 W 531.8 296.32 266.0 N 521.6 W 585.5 297.02 -151.9 304.50 270.1 N 527.6 W 592.7 297.11 /lOO 1.16 2.03 1.67 1.83 1.71 0.65 0.33 0.52 0.39 ]..15 ] . '18 1.1.8 1.38 1..68 1..79 ]..82 2.17 2.38 2.20 2.31 ]..98 2.41 2.37 2.90 2.68 3.87 221A-23 Page 3 08/29/9]. RECORD OF SURVEY MEAS DEPTH INCLN VERTICAL-DEPTHS SECTION ANGLE BKB SUB-SEA DISTNCE 2939 38.10 2819.3 2714.3 -153.3 2985 38.40 2855.5 2750.5 -157.1 3017 37.85 2880.6 2775.6 -160.4 3047 37.25 2904.4 2799.4 -164.0 3084 36.80 2934.0 2829.0 -169.1 3115 37.35 2958.7 2853.7 -173.8 3208 38.00 3032.3 2927.3 -189.0 3333 38.40 3130.5 3025.5 -209.6 3455 38.60 3226.0 3121.0 -229.3 3578 39.40 3321.6 3216.6 -248.4 DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD 305.40 276.4 N 536.7 W 303.20 292.5 N 560.2 W 301.50 303.1 N 576.9 W 299.50 312.3 N 592.6 W 297.90 323.0 N 612.2 W 296.70 331.6 N 628.8 W 296.20 356.9 N 679.7 W 296.80 391.4 N 748.9 W 297.10 425.8 N 8]6.6 W 298.20 461.8 N 885.1 W CLOSURE DISTNCE AZIMUTH DL /lOO 603.7 297.25 2.93 632.0 297.57 1.96 651.6 297.71 2.64 669.9 297.79 3.16 692.2 297.82 1.97 710.9 29'7.81 2.28 767.7 297.71 0.73 845.0 297.60 0.37 920.9 297.54 0.19 998.3 297.55 0.74 3699 39.60 3415.0 3310.0 -266.9 3849 40.30 3530.0 3425.0 -289.0 4001 40.40 3645.8 3540.8 -309.1 4153 40.50 3761.5 3656.5 -327.0 4306 40.60 3877.7 3772.7 -343.5 298.00 498.0 N 953.0 W 299.40 544.3 N ].037.5 W 300.90 593.7 N 1122.6 W 302.10 645.2 N 1206.7 W 302.70 698.5 N 1290.7 W 1075.3 297.59 0.18 1171.6 297.68 0.61 1269.9 297.87 0.42 1368.3 298.13 0.34 1467.6 298.42 0.18 4457 41.00 3992.0 3887.0 -359.1 4612 40.90 4109.1 4004.1 -374.4 4769 41.20 4227.5 4122.5 -388.3 4921 41.20 4341.9 4236.9 -400.9 5073 41.30 4456.1 4351.1 -413.2 5227 41.20 4571.9 4466.9 -423.9 5382 41.40 4688.4 4583.4 -432.2 5536 41.30 4804.0 4699.0 -438.2 5690 41.30 4919.7 4814.7 -442.3 5844 40.70 5035.9 4930.9 -444.4 303.00 752.0 N ]373.5 W 303.70 807.9 N 1458.4 W 304.70 865.8 N 1543.7 W 304.70 922.8 N 1626.0 W 305.20 980.2 N 1708.1 W 306.60 1039.8 N 1790.4 W 308.00 1101.8 N 1871.8 W 309.20 1165.2 N 1951.3 W 310.00 1230.0 N 2029.6 W 311.60 1296.0 N 2106.1 W 1565.9 298.70 0.28 1667.2 298.98 0.20 1769.9 299.29 0.34 ].869.6 299.58 0.00 1969.4 299.85 0.16 2070.4 300.].5 0.40 2172.0 300.48 0.42 2272.7 300.84 0.35 2373.2 301.22 0.23 2472.9 301.61 0.59 5999 41.00 5153.1 5048.1 -443.8 313.00 1364.3 N 2181.1 W 2572.6 302.03 0.43 Survey Codes: 3/MWD RECEIVED SEP _ 5 1991 -:-;:.. choram. .... 221A-23 Page 4 08/29/9]. RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 6155 41.30 6309 41.60 6428 42.20 6489 42.50 6519 41.80 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5270.6 5165.6 -441.8 5386.0 5281.0 -439.3 5474.6 5369.6 -436.7 5519.7 5414.7 -435.0 5541.9 5436.9 -433.8 DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD 313.10 1434.4 N 2256.1 W 313.70 1504.4 N 2330.1 W 313.90 1559.4 N 2387.5 W 314.90 1588.2 N 24].6.9 W 315.90 1602.5 N 2431.0 W CLOSURE DL DISTNCE AZIM[JT}{ /100 2673.4 302.45 0.]9 2773.6 302.85 0.26 2851.6 303.].5 0.5]. 2892.0 303.3] 0.90 29].].6 303.39 2.76 6550 40.70 5565.2 5460.2 -432.0 6582 40.30 5589.6 5484.6 -429.3 6613 40.10 5613.3 5508.3 -426.0 6630 39.80 5626.3 5521.3 -424.0 6771 38.70 5735.5 5630.5 -403.0 318.10 1617.4 N 2444.9 W 320.40 1633.2 N 2458.5 W 322.40 1648.8 N 2471.0 W 323.40 1657.5 N 2477.6 W 327.70 173]..1 N 2528.0 W 293].5 303.49 4.66 2951.5 303.60 3.26 2970.6 303.71 2.75 2980.9 303.78 2.99 3063.9 304.40 1.42 6925 38.70 5855.'7 5750.7 -375.8 7081 38.40 5977.7 5872.7 -346.8 7234 37.90 6098.0 5993.0 -317.4 7382 37.20 6215.3 6110.3 -287.4 7477 36.80 6291.2 6186.2 -267.1 329.00 1813.0 N 2578.5 W 329.70 1896.7 N 2628.1 W 330.40 1978.6 N 2675.3 W 332.50 2057.8 N 2718.4 W 332.90 2108.6 N 2744.6 W 3]52.] 305.11 0.33 3241.0 305.82 0.26 3327.4 306.49 0.37 3409.4 307.13 0.70 3461.1 307.53 0.45 7634 36.90 6416.8 6311.8 -232.5 7789 37.90 6540.0 6435.0 -195.5 7909 38.90 6634.0 6529.0 -164.4 7956 39.60 6670.4 6565.4 -151.5 7970 39.60 6681.2 6576.2 -147.6 8002 39.30 6705.9 6600.9 -138.4 8034 38.60 6730.8 6625.8 -128.8 8065 37.50 6755.2 6650.2 -119.5 8096 36.70 6779.9 6674.9 -109.8 8127 36.40 6804.8 6699.8 -99.7 334.10 2192.8 N 2786.6 W 336.20 2278.3 N 2826.2 W 337.00 2346.7 N 2855.8 W 338.10 2374.2 N 2867.1 W 338.00 2382.4 N 2870.5 W 339.80 2401.4 N 2877.8 W 340.90 2420.4 N 2884.6 W 341.90 2438.5 N 2890.7 W 344.10 2456.3 N 2896.1 W 346.40 2474.2 N 2900.8 W 3546.0 308.20 0.28 3630.1 308.87 0.82 3696.3 309.41 0.87 3722.5 309.63 ]..77 3730.4 309.69 0.29 3748.1 309.84 2.44 3765.5 310.00 2.56 3781.8 310.15 3.74 3797.5 310.30 3.62 3812.7 310.46 2.79 8158 36.30 6829.8 6724.8 -89.1 347.50 2492.1 N 2905.0 W 3827.4 310.63 1.28 Survey Codes: 3/MWD C21A-23 Page 5 08/29/9] RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE __ 3 8189 36.60 3 8217 36.80 3 8317 36.90 3 8440 37.80 ] 8565 37.70 VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE AZIMUTH FROM-WELL-HEAD 6854.7 6749.7 -78.1 350.00 2510.2 N 2908.6 W 6877.2 6772.2 -67.7 351.10 2526.7 N 2911.3 W 6957.2 6852.2 -27.9 355.90 2586.2 N 2918.1 W 7055.0 6950.0 24.4 357.10 2660.7 N 2922.7 W 7153.8 7048.8 79.5 359.00 2737.2 N 2925.3 W 8666 37.60 7233.8 7128.8 126.0 2.50 2798.9 N 2924.4 W 8809 37.80 7346.9 7241.9 193.5 2.50 2886.2 N 2920.6 W 8879 37.90 7402.2 7297.2 226.8 3.20 2929.1 N 2918.5 W 9024 38.40 7516.2 7411.2 297.9 5.80 30]8.4 N 2911.5 W **** Sidetrack Tie-in Station **** 9178 39.10 7636.3 7531.3 376.5 7.40 3114.2 N 2900.4 W CLOSURE DL DISTNCE AZIMUTH /100 3842.0 310.79 3.03 3854.8 310.95 1.58 3899.2 311.55 ].73 3952.4 312.3] 0.82 4006.2 313.]0 0.57 4048.0 313.74 1.29 4106.1 314 . 66 0. ].4 4]34.9 315.]0 0.40 4].93.7 3]6.03 0.77 4255.6 3]_7 . 04 O. 61 9360 39.90 7776.7 7671.7 475.2 13.60 3227.9 N 2879.3 W 9424 40.60 7825.6 7720.6 510.9 9.50 3268.4 N 2871.0 W · 9485 43.00 7871.1 7766.1 547.1 21.00 3307.6 N 2860.4 W '9507 43.80 7887.1 7782.1 561.2 19.60 3321.8 N 2855.1 W 9541 44.70 7911.4 7806.4 583.1 20.20 3344.1 N 2847.0 W 4325.5 3]8.2'7 ].4'7 4350.3 318.70 2.92 4372.9 3]_9.1.5 9.61 4380.2 3].9.32 4.75 439]..9 319.59 2.79 9572 44.50 7933.5 7828.5 603.4 21.20 3364.4 N 2839.3 W 9603 45.20 7955.5 7850.5 623.9 21.70 3384.8 N 2831.3 W 9634 46.00 7977.1 7872.1 644.6 21.10 3405.4 N 2823.3 W 9666 47.00 7999.2 7894.2 666.4 21.50 3427.0 N 2814.8 W 9898 46.70 8157.8 8052.8 824.7 21.00 3584.8 N 2753.5 W 4402.4 3]9.84 ]..7] 4412.9 320.09 2.40 4423.5 320.34 2.77 4434.9 320.60 3.20 4520.2 322.47 0.17 10423 44.50 8525.1 8420.1 1184.0 30.00 3923.0 N 2592.2 W 10740 45.00 8750.3 8645.3 1403.8 34.00 4112.2 N 2473.9 W 10800 45.10 8792.7 8687.7 1445.9 35.00 4147.2 N 2449.9 W 10827 44.90 8811.7 8706.7 1464.8 35.30 4162.8 N 2438.9 W 10858 45.00 8833.7 8728.7 1486.6 36.30 4180.6 N 2426.1 W 4702.0 326.54 0.94 4799.0 328.97 0.65 4816.8 329.43 0.85 4824.6 329.63 0.92 4833.5 329.87 1.64 10874 44.60 8845.0 8740.0 1497.8 36.90 4189.6 N 2419.4 W 4838.0 330.00 3.11 Survey Codes: i/SINGLE SHOT 3/MWD C21A-23 Page 6 0S/29/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 3 10891 44.40 3 10920 43.60 3 10933 43.40 3 10948 43.60 3 10964 43.50 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 8857.2 8752.2 1509.7 8878.0 8773.0 1529.8 8887.5 8782.5 1538.7 8898.3 8793.3 1549.0 8909.9 8804.9 1560.0 3 ~10974 44.30 8917.1 8812.1 1567.0 3 10991 45.50 8929.2 8824.2 1579.0 3 11023 46.40 8951.4 8846.4 1601.9 3 11038 46.40 8961.8 8856.8 1612.8 3 11055 46.90 8973.4 8868.4 1625.1 DIRECTION AZIMUTH RELATIVE-COORDINATES FROM-WELL-HEAD 37.30 4199.1 N 2412.2 W 38.20 4215.1 N 2399.8 W 38.40 4222.1 N 2394.3 W 38.30 4230.2 N 2387.9 W 39.20 4238.8 N 2381.0 W 39.20 4244.1 N 2376.6 W 39.80 4253.4 N 2369.0 W 38.70 4271.2 N 2354.4 W 37.90 4279.7 N 2347.7 W 37.70 4289.5 N 2340.1 W CLOSURE DISTNCE AZIMUTH 4842.7 330.12 4850.4 330.34 4853.7 330.44 4857.6 330.56 4861.7 330.68 4864.3 ~330.75 4868.6 330.88 4877.2 331.14 4881.4 331.25 4886.3 33].39 DL /lOO 1.65 3.13 1.70 ]..37 2.74 8.00 7.28 3.34 2.80 3.01 3 11070 47.40 8983.6 8878.6 1636.1 3 11086 47.70 8994.4 8889.4 1647.9 3 11091 47.60 8997.8 8892.8 1651.5 3 11101 47.60 9004.6 8899.6 1658.9 3 11118 47.60 9016.0 8911.0 1671.4 38.20 4298.2 N 2333.4 W 38.00 4307.5 N 2326.1 W 38.20 4310.4 N 2323.8 W 37.80 4316.2 N 2319.2 W 37.70 4326.1 N 2311.6 W 4890.7 33]..50 4895.4 331.63 4896.9 331.67 4899.8 331.75 4905.0 331.88 3.79 2.00 2.96 2.18 0.32 11133 47.70 9026.1 8921.1 1682.5 11149 48.00 9036.9 8931.9 1694.3 11164 48.00 9046.9 8941.9 1705.4 11181 48.50 9058.2 8953.2 1718.0 11212 49.10 9078.6 8973.6 1741.3 11245 50.00 9100.0 8995.0 1766.4 11326 50.80 9151.7 9046.7 1828.8 11619 54.00 9330.4 9225.4 2060.5 11830 54.50 9453.7 9348.7 2230.1 12290 55.00 9719.2 9614.2 2589.5 37.20 4334.9 N 2304.8 W 36..40 4344.4 N 2297.7 W 36.60 4353.4 N 2291.1 W 37.00 4363.5 N 2283.5 W 38.40 4382.0 N 2269.2 W 39.70 4401.5 N 2253.4 W 43.00 4448.3 N 2212.2 W 47.00 4612.4 N 2048.1 W 52.50 4723.0 N 1917.4 W 64.50 4919.0 N 1597.7 W 4909.6 332.00 4914.6 332.13 4919.4 332.24 4924.9 332.38 4934.7 332.62 4944.8 332.89 4968.0 333.56 5046.7 336.06 5097.4 337.90 5171.9 342.01 1.94 3.34 0.74 3.22 3.23 3.58 2.64 1.41 1.74 1.75 'Survey Codes: i/SINGLE SHOT 3/MWD J/PROJECTED 221A-23 DATA INTERPOLATED FOR 100 Page FT SUBSEA INTERVAL 7 08/29/91 ~UBSEA MEAS )EPTH DEPTH INCLN TVD MD-TVD VERT ANGLE BKB DIFF CRRT DIRECTION AZIMUTH RELATIVE COORDINATES FROM WELL HEAD 100 205 200 305 300 405 400 505 500 605 600 705 700 805 800 905 900 1006 1000 1106 0.19 205 0 0 0.37 305 0 0 0.25 405 0 0 0.96 505 0 0 1.86 605 0 0 3.16 705 0 0 2.92 805 0 0 3.87 905 0 0 5.69 1005 1 0 7.27 1105 1 1 351.30 0.23 N 0.28 E 86.81 0.50 N 0.57 E 297.45 0.71 N 0.75 E 277.99 0.90 N 0.39 W 277.83 1.16 N 2.74 W 300.98 2.66 N 6.86 W 298.54 5.28 N 11.35 W 289.11 7.64 N 16.64 W 282.88 9.95 N 24.69 W 281.17 12.22 N 35.97 W 1100 1207 1200 1308 1300 1409 1400 1510 1500 1611 7.08 1205 2 1 6.61 1305 3 1 7.67 1405 4 1 8.82 1505 5 1 10.02 1605 6 1 277.15 14.32 N 48.49 W 274.72 15.50 N 60.41 W 281.17 17.17 N 72.74 W 288.00 20.73 N 86.78 W 290.95 26.33 N 102.39 W 1600 1713 1700 1815 1800 1918 1900 2022 2000 2~27 2100 2233 2200 2341 2300 2451 2400 2564 2500 2679 11.26 1705 8 2 12.77 1805 10 2 14.55 1905 13 3 16.42 2005 17 4 18.58 2105 22 5 21.07 2205 28 6 23.51 2305 36 8 26.00 2405 46 10 28.31 2505 59 12 31.04 2605 74 15 291.20 33.01 N 119.92 W 293.29 41.07 N 139.56 W 295.25 51.02 N 161.70 W 296.92 63.25 N 186.54 W 297.46 77.67 N 214.49 W 298.36 94.50 N 246.33 W 299.26 114.28 N 282.28 W 301.10 137.40 N 322.15 W 301.47 163.93 N 365.97 W 302.97 194.31 N 414.20 W 2600 2797 34.23 2705 92 19 303.76 229.57 N 467.42 W C21A-23 DATA INTERPOLATED FOR Page 100 FT SUBSEA INTERVAL 8 08/29/91 SUBSEA DEPTH 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 MEAS DEPTH 2921 3048 3173 3300 3428 3557 3686 3816 3947 4079 4210 4342 4474 4607 4739 4872 5005 5138 5271 5404 5537 5670 5803 5935 6068 INCLN ANGLE TVD MD-TVD BKB DIFF 37.69 2805 116 37.24 2905 143 37.76 3005 168 38.30 3105 195 38.56 3205 223 39.26 3305 252 39.58 3405 281 40.15 3505 311 40.36 3605 342 40.45 3705 374 40.54 3805 405 40.70 3905 437 40.99 4005 469 40.90 4105 502 41.14 4205 534 41.20 4305 567 41.26 4405 600 41.26 4505 633 41.26 4605 666 41.39 4705 699 41.30 4805 732 41.30 4905 765 40.86 5005 798 40.88 5105 830 41.13 5205 863 VERT DIRECTION CRRT AZIMUTH 24 304.49 27 299.47 26 296.39 27 296.64 28 297.03 28 298.01 30 298.02 30 299.09 31 300.37 31 301.51 31 302.32 32 302.77 32 303.08 32 303.68 33 304.51 33 304.70 33 304.98 33 305.79 33 307.00 33 308.17 33 309.21 33 309.90 33 311.18 32 312.42 33 313.04 RELATIVE COORDINATES FROM WELL HEAD 270.05 N 527.52 W 312.55 N 593.02 W 347.52 N 660.63 W 382.33 N 730.81 W 418.21 N 801.63 W 455.35 N 873.]_2 W 494.14 N 945.73 W 533.95 N 1019.07 W 576.01 N 1092.73 W 6]_9.82 N 1165.72 W 665.05 N 1238.15 W 711.18 N 1310.36 W 758.18 N 1383.00 W 805.91 N 1455.45 W 854.66 N 1527.48 W 904.46 N 1599.46 W 954.43 N 1671.40 W 005.14 N 1743.06 W 057.14 N 1813.59 W 110.81 N 1883.30 W 1165.81 N 1951.97 W 1221.75 N 2019.70 W 1278.42 N 2086.07 W 1335.95 N 2150.36 W 1395.10 N 2214.08 W 5200 6201 41.39 5305 896 33 313.28 1455.06 N 2278.13 W C21A-23 DATA Page INTERPOLATED FOR 100 FT SUBSEA INTERVAL 9 08/29/91 SUBSEA DEPTH 530O 540O 5500 5600 5700 58OO 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 MEAS DEPTH 6334 6469 6602 6732 6860 6988 7116 7243 7369 7494 7619 7745 7872 8001 8127 8252 8377 8503 8630 8756 8883 9010 9138 9267 9397 INCLN ANGLE 41.73 42.40 40.17 39.01 38.70 38.58 38.29 37.86 37.26 36.81 36.89 37.61 38.59 39.31 36.40 36.83 37.34 37.75 37.64 37.73 37.91 38.35 38.92 39.49 40.30 TVD MD-TVD VERT DIRECTION BKB DIFF CRRT AZIMUTH 5405 929 34 313.74 5505 964 35 314.57 5605 997 33 321.70 5705 1027 30 326.51 5805 1055 28 328.45 5905 1083 28 329.28 6005 1111 28 329.86 6105 1138 27 330.53 6205 1164 26 332.32 6305 1189 25 333.03 6405 1214 25 333.99 6505 1240 26 335.60 6605 1267 27 336.75 6705 1296 29 339.74 6805 1322 26 346.41 6905 1347 25 352.77 7005 1372 25 356.49 7105 1398 26 358.06 7205 1425 26 1.24 7305 1451 26 2.50 7405 1478 27 3.26 7505 1505 27 5.54 7605 1533 28 6.98 7705 1562 29 10.42 7805 1592 30 11.23 RELATIVE COORDINATES FROM WELL HEAD 1516.06 N 2342.33 W 1578.69 N 2407.30 W 1643.33 N 2466.70 W 1710.45 N 2514.69 W 1778.34 N 2557.47 W 1846.89 N 2598.77 W 1915.35 N 2638.98 W 1983.31 N 2677.97 W 2050.84 N 2714.76 W 2117.79 N 2749.31W 2184.87 N 2782.74 W 2253.56 N 2815.12 W 2325.28 N 2846.64 W 2400.72 N 2877.54 W 2474.33 N 2900.85 W 2547.29 N 2914.23 W 2622.33 N 2920.50 W 2699.45 N 2924.29 W 2776.71 N 2925.17 W 2853.80 N 2922.05 W 2931.32 N 2918.37 W 3009.58 N 2912.35 W 3089.00 N 2903.56 W 3169.69 N 2891.68 W 3251.17 N 2874.19 W 7800 9532 44.46 7905 1627 35 20.04 3338.16 N 2849.20 W 221A-23 DATA INTERPOLATED FOR 100 Page 10 FT SUBSEA INTERVAL 08/29/91 ~UBSEA DEPTH 7900 8000 8100 8200 8300 84O0 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 MEAS DEPTH 9675 9821 9967 10111 10254 10395 10535 10676 10817 10957 11102 11253 11411 11576 11746 11918 12091 12265 INCLN TVD MD-TVD VERT ANGLE BKB DIFF CRRT 46.99 8005 1670 43 46.80 8105 1716 46 46.41 8205 1762 46 45.81 8305 1806 44 45.21 8405 1849 43 44.62 8505 1890 41 44.68 8605 1930 40 44.90 8705 1971 41 44.97 8805 2012 41 43.54 8905 2052 40 47.60 9005 2097 44 50.08 9105 2148 51 51.73 9205 2206 59 53.53 9305 2271 65 54.30 9405 2341 70 54.60 9505 2413 72 54.78 9605 2486 73 54.97 9705 2560 74 DIRECTION AZIMUTH RELATIVE COORDINATES FROM WELL HEAD 21.48 3432.86 N 2812.54 W 21.17 3532.39 N 2773.69 W 22.18 3631.10 N 2735.16 W 24.65 3726.48 N 2693.86 W 27.09 3818.05 N 2649.40 W 29.52 3905.78 N 2602.05 W 31.41 3990.67 N 2551.98 W 33.19 4074.56 N 2498.94 W 35.19 4157.31 N 2442.78 W 38.82 4235.13 N 2383.94 W 37.80 4316.58 N 2318.94 W 40.01 4406.03 N 2249.61 W 44.16 4496.49 N 2166.34 W 46.41 4588.63 N 2073.31 W 50.32 4680.60 N 1970.60 W 54.81 4765.73 N 1859.41 W 59.32 4842.48 N 1740.95 W 63.85 4910.13 N 1615.94 W C21A-23 DATA Page 11 INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 08/29/91 MEAS INCLN VERT-DEPTHS SECT DEPTH ANGLE BKB SUB-S DIST 1000 5.59 999 894 -9 2000 16.02 1984 1879 -76 3000 38.14 2867 2762 -159 4000 40.40 3645 3540 -309 5000 41.25 4401 4296 -407 6000 41.00 5154 5049 -444 7000 38.56 5914 5809 -362 8000 39.32 6704 6599 -139 9000 38.32. 7497 7392 286 10000 46.27 8228 8123 894 11000 45.75 8935 8830 1585 12000 54 . 68 9552 9447 2365 DIRECTION AZIMUTH 283.25 296.65 302.40 300.89 304.96 REL-COORDINATES FROM-WELLHEAD 10 N 24 W 61 N 181 W 298 N 568 W 593 N 1122 W 953 N 1669 W 313.00 1365 N 2182 W 329.34 1853 N 2603 W 339.69 2400 N 2877 W 5.37 3004 N 2913 W 22.75 3653 N 2726 W 39.49 4258 N 2365 W 56.93 4803 N 1804 W CLOSURE DIST AZIMUTH 26 292.13 191 288.47 641 297.65 1269 297.87 1921 299.72 2573 302.03 3195 305.45 3747 309.83 4184 315.88 4558 323.27 4871 330.95 5131 339.41 DL/ 100 1.8 1.8 2.7 0.4 0.2 0.2 0.3 2.4 0.8 1.0 3.3 1.7 ,11 i SHELL ~ESTERN EaP ;NC . <KE])o i~ ~ i 391 C2&A-23 VERTICAL SECTION ViE~ , , , Section at: 41.96 T',/O Scale.' ! inch = ilO0 feet Deo Scale.'1 inch = 1100 feet Drawn · 06129/gi Marker Identification MO TVD SECTN At KB 0 0 0 BI TIE-IN TO :11-29 9176 7696 976 C) TD 12290 97~9 2590 INCLN 0.00 99.~0 55.00 4400- 5500-~----- l I I l ; ! ! 1 I l I · I I ! l 7700- 8800 9900 ! I ! -' I I I I ' ! ! 1 0 2200 3900 Sectian Oel~arture 4400 §500 SHELL WESTERN E6, P iNC. ~arker IdentifJcatton ~l KB B) TiE-iN TO C:~-23 , 0 0 N 0 9~7B 3t~4 N 2900 , , , C2!A-23 PLAN ViEW CLOSURE .....: 5172 ft 342.01 DECLINATIO~(.' 0.00 SCALE .......: i inch = 800 feet DRAWN .......: 0B/29/91 Srest Lsn~ flir~:~ionai flrilling 3EO0 ....................................................... · . t I BOO - .. 0" , . 4000 , 3EO0 2400 i600 BO0 0 <- NEST · EAST -> EP-1034 (Rev. 10-80) O SHELL OIL COMPANY DRILLING'AND'WELL S ICINg" BOP, ACCUMULATOR & CHOKE MANIFOLD TEST REPORT (tn~trucfion$ on Reverse) ~LOW OUT .... ASSEMBLY . .. . .. was the outer valve where twO - i, /4 .-,,'.'-"-'" B. KELLY COCK ~RE3SURE TEST C. OTHER · · FRESSURE TESTS' Do CASING · PRESSURE TEST · . CHOKE MANIFOLD PRESSURE TEET. ACCUMUL^TOR & BOP CONTROL MANIFOLD G. REMOTE STATION Ho ACCUMULATOR PERFORMANCE T EST EQUIPMENT CH;CK TOP JOINT OF CASING t., ;;~.., jVALV£ POSITION ,'AI. VF.S TE.$TED.. IUSF'D ,J~C~ '' ON MANIFOLD L MOTE 60~. TESTED i~OLTS IN '°F" AS IN e, [] .o *,s D .o *- ,5 No / ' p- ~ - ACCUMULATOR VOLUME & T~PE - '- 18OTTL[ RECH G~ R[SSURE ~ EDUCING & REGULAT. V. ~YD~UL~C PUM~' tFLUID O~RATING PR~SS~R~ IN~T AIR .s, ~",..'/'/'/'~ -.~°~' ~t ~.~.~:.~.~- ~=,. ~~~. ~ "' ~.~ :" ~.o"- ' ~ · ' ~ GUARD O~ ~,. nN. ,,. /~ ~lyllrll os, . [] ~'.. '/~o Accumu~a:o~ & Puml~ j Accumula&or Only J Pump Only _~,,..~,.... i,'"',',',,..*L t ~,,,,,,g Time. t t "' t/~ !~,,~ !~o~rot tPLATFORM SHUTDOWN IRfG 1--~ v~ FLOOR P~elJUre !INITIALI FINI&I. { iJ. LEAKS ACCUMUL~ T .,--.- .-.- · :.; I I t .! -, PIT DRILL Drilllrl9 Tr SHELL OIL CO,V, PAN¥ BLOW OUT PREVENTER ASSEMBLY PRESSURE TEST BOP, ACCUMULATOR Ex CHOKE MANIFOLD TEST REPORT · [/n$'uuc,on$ on B. KELLY COCK . P~ E~SURE TEST OTHER · · PRESSURE TESTS .... Do CASING · PRESSURE TEST LOCKm9 wneets ,nslalleO ~T~I$ [~ NO --' " i~ISSUfl Git ca$1ng/c_J!.lg aflnuiu$ - ."C. ' _ '.. r. . · · ; :" . .: ..~q :.-..... .... ~...'. CHOKE UANiFOLD PRESSURE TE_~I' . ACCUMULATOR ' ' & SOP C0,~;TROL MANIFOLD REMOTE STATION H. ACCUMULATOR PERFORMAr~CE By " F~t · BY - Plt --- -: -'. ..... SIN "F~ I~CCMMU~ATOR VOEUM[ & TY~[ . .~ LJSI CnKke~ ' ~ MANUFACTURER , . · .'~- ..... ..__ ~. ., : ,- ~. WER SUPPLY ICO~TION J~ABCLL[D CURRENTCY IB~iNO RAM CONTROC ~ ~.o /ZO -, Dy. '~"'G~°°"Dv. ~[CNARG~ TIM[ .... ..... . - TEST !. EQUIPUENT CHECK Too P~ot Rams Mtaale Rams lBottom Rams All ItyglraullC&tly I t I I','~-SI NO CJrCLIlatlrlg I'l~aO Off tlOOt 1 ~IflsICIt IRO~'$ O~ llOOf level IrlOlCatOt mnStal/eg & vv~.-,~ ~, Reacllorl I mm'l. ClOlefl. lead, HOUSTON ~'wnire catv · RIG - p,nk con), ' .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CONHI$$10N BOPE lnapection Report , DATE OPERATION.* D?lg ~ Wkvr.__._ Location~ See _:3 ~ T ~ ,~ R t',~/~./' ~ .~,,v'~ fY, HUD SYSTEHS~ '" Vtau'`l Audio Trtp tank ~/e~ ! ~/'~'_~ Flow BOPE STACKt Annular preventer Blind rams Choke line valves HeR valve Kill,line valves Cheek valve Te'`t Prellure __ _g..8-. o_/..Fo o a 9 /, o ~ull charge pre.sure ..... ~~.~, Pree~ after closure ,/~'00 ,, pslg Pump 1nor sloe presa 200 Con~Pol~ Nester ..... ~0 , ,, __ Ramote~Bltnd awlteh KELLY AND F~OOR UppeP Ke11~ ~ Test Lower Kelly ~ Te~t 8'`11 ~pe ~ Tea~ In~de BOP ~ Tee~ Choke manifold Number v'`Ivet ,/ ~ Number flangel ..... Z//~ AdJua~able choke'` Hydraulically opera,ed choke / TE_ST RESULTS; Fa(lures_ ._ ~ Tm=t time q hri Repair or replaoement of failed equ~pmen~ tD be made day,,, Notl fy the Inspeotor, and fo11~ with wrftten/FAXed ver~floation to Com~isaion offioe, Remark~= Dtz~rtbu~ton~ ortg - AOQCC c - Operator o - ~upervtaor C.O0~ (rev 05110/90) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE inapection Report OATE 7/1 1/~ 1 i - := ':' '" ~RATIOHt O;erator Well Drlg X Wkvr C21A-23 See 23 T 8 (~e~e~a~) GOOD Mou~ekeep~g (ge~e~a~) GOOD N/A TEST: Intttel _ Weekly. _.~.__ Other .... Repreaentariva R.V. A/~LLS i_ i i iiii Permit # .9 1' - ~ 4 i u _ _~_._ .u,j,..,,,,, i We ! 1.: t gn ~ E S ACCUMUL~, ,.Tp_R. SYSTEM ~ Rig_GOOD Full charge premau~e~ ::- ~_000 . patg 36 see 2400 , - MUD SYSTEMS! Vi aual Audio pit gauge qES .......I qES 1800 Pump Inet olom prose 200 p~fg Full oharge pramm attained N2 6 BO77LES Controla! Heater ,, ,, .,m .... miff p~tg Gal de,reform , ~ ] ff~ KELLY AND FLOOR SAFETY~ALVE~I Upper Kelly ~ Test preaaurm 250/50~? e0PE STA¢~K~ Tee~ Pee~auee Lower Kelly yES ?e~t preaaure 250/5000 i ii .... ~[ ... - .... Annular preventer 2~/3~00 ,. Ball type ~ Te~t pressure 2~0/~000 Pipe ram~ 250/5~00' , lnatde COP ~ES Tea~ prealure 2~0/~, Blind rams 250/~000 .. Choke manifold ~ES Telt pressure 250/5000 Choke 1the valvea ~0/5©00 Number valvea ~ 3 HCR valve 2~0/~©0© N~mber flangel ~11 1~ne valve~ ~0/~00© AdJua:able ehokea Che=k valve 2~©/5000 Hydraulically operated choke TEST RESULTS= . Failures .... .NONE Te.~ time , ~ hrt Repair or replacement of failed equipment to be made Within day~. Notify the Inspector, and follow w~th wrttten/FAXed verification te Commission office. Remarks= Dt~tribution~ ort~ - AOGCC c - operator ~ - Superv~iO~ C.O0~ (rev 05/10/90) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CONHI$$1ON BOrE inspection Report Housekeeping (genoral)C~_~ Reserve Pump 1nor elo~ pre~ 200 p~fg paig _ patg , mtn ~see HUD SYSTEHSl Tr4p tank P4t gauge Flow monttor Pfpe rams Bt ~nd rams Choke 1the valves HC:R valve K]11 l~ne vaive~ ~'-(_~ Che~k valve Upper Kelly Lower Kelly Ball type lna]de BOP Choke mentfold Number valvee Number flangel . AdJue~eble ehokea. , Hydreulioally op,r~ted choke Full oharge premm attatned ~mtn Con~rola~ Heater .......... ~o~ ~ ........... Remote~ Bl~nd lwlCeh eover~ KELLY AND FLOOR ~AFETY ~ Test pressure / I'~ TEST RESULTS~ Repair or replaoement of fatled equipment te be made ~tth4n (~ day~. Notify the I nspeator~ and follow with wrftten/FAXed ver~fleatJon ta Co~faaJon office. grig - AOOCC c - Operator ~ - Superv~aor c.oOq (rev O$/la/~0) WITNESS, ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report DATE OPERATION: Drig, X~ Wkvr Operator SHELL WES. TERN Er~ "P/INC. C21A-23 Location: Sec 23 T 8/1/ R 13W M S/~ Drlg contrctr ........ ~,RACE DRLG. Location (general),,GOOD Well sign,, Housekeeping (general) ~00~ Rig. Reserve pit MUD SYSTEHS: Visual Trip tank X Pit gauge Flow monitor X Gas detectors X Audio BOPE STACK: Test Pressure Annular preventer 250/3500 Pipe rams 250/5000 Blind rams ~l 250/5000 Choke line valves 250/5000 HCR valve 250/5©00 Kill line valves 250/5000 Check valve 250/5000 TEST: Inttial~ Weekly /T Other Representative PAUL WHITE Permit # ~)1-44 ' 9 5/8" Rtg~ SHELL CRap ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump tncr clos press 200 psig Full charge press attained N2 2000 Casing set ~ 9,320 JOHNSON Controls: Master (WINDOW) ft 3000# pstg I 7'50 pstg mtn 22 sec mtn 40 sec pstg ...... Remote yES Blind switch cover yES KELLY AND FLOOR SAFETY VALVES: Upper Kelly X Test pressure 250/5000 Lower Kelly X Test pressure 250/5000 Ball type X Test pressure 250/5000 Inside BOP X Test pressure 250/5000 Choke manifold X Test pressure 250/5000 Number valves 1 3 Number flanges 26 Adjustable chokes ~ES Hydraulically operated choke ~ES TEST RESULTS: Failures "1'": Test time 3::"5 hrs Repair or'replacement of failed equipment to be made within ? days. Notify the Inspector~ and follow with written/FAXed verification to Commission office, THE BX160 RING GASKET BETWEEN 7HE DOUBLE STUDDED ADAPTOR (11":5:~"& Remarks: 13 5/8' 5K RISER) FAILED THE 5000# BOP 7£S7. WE RAN DRILL PIPE IN THE HOLE 7/11,285' 2 LAqED ~ _~200' PLUG. THEN PULLED UP 7HE HOLE & SET , , ; ,-, , ' ,~ E.4L~Iz~UR70# 9 5/$ S70/2;'i PAC/(.~_R ,47 555 . 7HEN NIPPLED DOWN 7HE z~OP SLATE OF ALASKA ALASKA OIL AND GAS COttSERVATION COHNISSION BOPE inspect:ion Report' / OPERATION; Drlg F~ Opera tot . ~'~/, ~ Z- L, Location= T ~/f~/ Location (general) ttousekeeplng (general) Wkvr Well sign Rig T~S~= Initialr Weekly / Other Representative PY~(~/.~. ~, ~ / /'"-/~' Permit, ACcoHU~ToR SYSTEH~ Full charge pressure ~000 pstg Press afeer closure / ~EO .slg HUD SYSTEHSI Trip tank Pit gauge Flow monitor Gas detectors Visual Audio BOPE STACK= Annular preventer Pipe rams Blind rams ~ Choke ll-ne valves HCR valve KII1 line valves Check valve Test Pressure 35oo Pump Incr tics press 200 pslg Full charge press attained Controls, Master ! ~ mln ~ ~" sec _ p, ~ ~/~0 ,.. Remote ''L.-/~ Blind switch cover KELLY AND FLOOR SAFETY VALVES= Upper Kelly · Lower Kelly Ball type Inside BOP Choke manifold Number valves Number flanges. AdJustable chokes Hydrau!lcally operated choke Test pressure ~'"""/Test pressure TEST RESULTSg Remarkst Failures ~ Test time ~, 0 hfs Repair or replacement of failed equipment to be made wlthtn ~, days. Notify the Inspector~ and follow with wrltten/FAXed verlfica/~on to Con~nisslon office, / I -- 5u,'_'~rvi tc.- ~' ? THES~ 'sEP ,51991 Alaska Oil & Gas Cons. ~u~m,, ~ch0rage STATE OF KA ALASKA OIL AND ~AS CONSERVATION CO~n~SSION ))OPE inspe¢~on Report MUD SYSTEHSs V( euel Audio T~t~ 'a"~ ...... I~~ I II ~ BOPE STACK~ Annular p~'even~:er Ptpe reran Choke 1 tee vel ve~ K~ll l(ne valves Cheek valve TEST: lntt4el m Repremen~atl ye Permi~ # Weekl y~___ Other .... cio f~ pmig pmtg Pump trot olom presm 200 pmig Full charge prams attained ii i Con~rola~ Me,tar Remote~/-~'~ altnd switch eover~/~'"~ KELLY AND FLOOR SAFETY VALV£St Upper Kelly Lower Kelly Ball type Inatde ~OP Choke manifold Number valvee Number flanges AdJue~eble ohokes ...... Nydreulioally operated choke mir 7~.~ · -~_ mJn-Z~ moa p~ig _. Test prensurm Te~t pressure Teat: pressure TEST RF_J~ULTS: Repair or replacement of fatled equipment to be made Wtthln . , days. Notify the Inspeotor, and follow with wrttten/FAXed vertftoatton to Commtamian offtce, DizbributJon~ ~rtg - c - Operator C,O0~ (rev 05/10/~0) STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COb(MISSION BO,rE Inspection Report OPERAT[ON~ OperatOr Well Locations See 1~/ T ~A/ R i,F3cL) M A~ ,TE,~T: Initial _ Weekly ./~___ Other , , ,, , ~ .., ........ Location (general) O.J~, Weil.~tgn~ H~u~ekeep~ ng (genera 1 )~ Ri g_~ ~, Reserve pit ~.. ~ ! ACC~U~7~ _SYST~, Full charge premmure ..... ... Prem~ after olomure mm Pump thor elms premm 200 _~000 ' pmtg .... MUD SYST~llSz. Visual Audio Trip tank O~ ~, , J ~< / / Flow men,tot _ __ 0¢~ ....... J ~'e..~ BOPE STACK= Annular preven)er Pipe ramm B)tnd rams :hoke line valvem HCR valve Kill l~ne valves Che~k valve Test Pressure . Full oharge press attained ~_. mtn __ a2 . /000 Con~rols~ Master C/.~ ..... Remote C/~ Blind switch cover KELLY AND FLOOR SAFETY YALVESt Upper Kelly La,er Kelly Ball type ._~ Inmide BOP ~hoke manifold Number valves Number flangem .. Adjustable ohekem .i Hydrsultoally operated choke TEST RESULTS Remarks= F-llur,~ 0 Tame time ~_ A/~-, bps Repa(r or repleoem~flt of failed equipmen~ to be mmda Within ,0 days. Notify the Inmpeetor, and follew with wrttten/FAXed verification to Commission office. ortg - AOQCC ¢ - ODerator c - ~upervt~Or C.OOq (rev O~/lO/gO) WITNESS' . ......... ~ . ii TO: THRU: FROM: MEMORANL UM Sta e of Alaska ALASKA OIL/~D GAS CONSERVATION COMMISSION / Lonnie C. S~~/ DATE: June 24, 1991 Commlssioner//'~ t~-~ FILE NO: l'.G6 2 4 Lou Grimaldi ~~ Petroleum Inspector TELEPHONE NO: SUBJECT: BOP Test Shell "C" 21A-23 Middle Ground Shoal Permit No. 91-44 June~ 20. 1991: I travelled to Shell's Platform "C" in the Middle Ground Shoal of Cook Inlet to witness a BOP test. The rig is presently redrillinG 21A-23. I was extremely impressed with the rig and the test. All equipment I observed functioned flawlessly and the rig hands appeared quite competent during the test. Weekly BOP tests and daily function tests were duly noted in the IADC log along with frequent blowout drills. I followed both the choke and the kill lines and found proper size and targets throughout. The BOP stack had just been overhauled and was anchored securely. Although this is one of the older rigs in the inlet, it appears to be one of the best maintained. In summary: The BOP test on Shell "C" went smoothly with no failures. Attachment. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 OPERATION: Drlg Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COHHISSION BOPE Inspection Report' TEST: Initial, , _ Weekly / Other ,, Representative p~l~ ACcuHU~ToR SYSTEM ~ Full charge pressure Pres, afeer ,lo,ure Pump incr cio, press 200 pstg ~ mln ~ ~ sec Full charge press attained ~ mln ~_ sec Wkvr Drig contrctr. ~ Location (general) tlousekeeplng (general) Reserve pit ~/ ~ Well sign RIg.~ HUD SYSTEHS: Visual Audio Trip tank , Pit gauge I Flowmonleor Gas detectors BOPE STACK: Annular preventer Pipe rams Blind rams ~ Choke ll,ne valves HCR valve KIll line valves Check valve 3~(~'Test: P~ssure fl: pslg pstg Remote ''L~/' Blind switch cover KELLY AND FLOOR SAFETY VALVES Upper Kelly . Lower Kelly Ball type Inside BOP Choke manifold I ~'""'" Test; pressure ~-~Test pressure ~"~' lest pressure /~ Test pressure ~ Iesb pressure Number valves /~ Number flanges_ ~'} Adjustable chokes ~ Hydraulically operated choke TEST RESULTS: Failures ~) Test ttme ,._~/0 hrs Repair or replacement of failed equipment to be made within (~:~_ days. Not;tfy the Inspect;or~ and follow with wrttten/FAXed veriflcat;Ion to Commission office. Remarksl Distribution: orlg - AOGCC c - Operator c - Supervisor C,OOq (rev 05/10/90) W I TNESS AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PEI~MIT X _t~! - L..~_ q WELL NAME ~,~'~ , ~ ~'l ~ "'" COMPLETION DATE ~ ,/,, ,,.~"! ~1 CO. CONTACT ~' ~ Check_o. ff or Iisi data as' it is received..l!st receivt~d ~late for 407'. if not rt~tll~ired list as NFi' cored inte~a!s ,, core a,~al~sis ..... d~ ditch iqte~als diu, ita,i data ...................... ~0 t~..V, ff Il llllllll lllllllllllllllll I ~I I I I I I I II III I I II I I t I i i i iii ii iii i i . i iii ii i iiii i i ii i ii iii ii i i ~ i i i i JJl i i i L Il.fl I I I I I I III I I I : LOG TYPE ' RUN " INTERVALS SCALE ...... NO. {to the nearest foot] .... {inch~100"] ~ .~~/,m,u~ / ~,~ ......... !,,,,-a ,, ,~t~,o,,,- ~,~-~1 ....... 2 , ,,,: .... : ,, ~ ~~ I,,~1~ ....I-~- eltl)O' I::Z'~,,t"cl , ,~ ,, Il t LIl L tJ i ii ii i Il Il ~ , , ,,,,.,~ ,, ~ ~ , , ,, ,, i i iii i .i i i~11 ill i J iii ii i iii i ii ii ii ii i iii i iiii /i iii i i i L I11 II ,Ill ii i i iii iiii ii iii Il IUI "~i ' , ..................................... 161 .~,_,, ._~,_, ,,,~,,, ~ . TO ANCHORAGE E×PRES~ P.O. Box 200503 ANCHORAGE. ALASKA 99520,,0503 (~7) 56 t- I009 EIN 92-0129384 'DATE SHIP TO 85054 ORDER NO. ,& TRIPLICATE An( I/ ].,:,'s'.~O Ne.O!1, P.02 ATLAS WtRELINE FOR STATE OIL AND GAS CONSERVATZON COMMISSION ATTENTION LARRY GRANT, LIBRARIAN AT 3001 I~ORCUPI'NE DRIVB WELL ¢2IZ1~23 ,($]1~.~.1 ) "~-"~ PRINTS NEG, ~- SEPIA NEG, SEP;A NEG. ~ SEPIA ___.__ NEG, __._,..- SEPIA NEG..-..__- SEPIA NEG, ~ SEPIA __,.___ NEG, _.____ SEPfA _.._____ NEG.-_._--- SEPIA -~- ~~ , PRINTS ~_ ~~ -~ C.~,~__Ft,._. ' ~ PRINTS _______ ~. .. , _/. ~PRINTS ~ PRINTS ~ ...... _ ...... . PRINTS ~ ~~ PRINTS ~ PRINTS SIGNED DATE RETAIN THIS SECTION FOR YOUR RECORDS RE C21A~23 - -- .i -,-, ~: ,J ,. ,, ~, DLL-MLL-GR C.Z ", --~ ") ]"~PRINTS ~--~.. ?~-~7~- .__.__.._PRINTS_____ ____ PRINTS ~ ~~ PRINTS ~ ~ PRINTS ~ ~ PRINTS ~ PRINTS ~ ~. PRINTS ~ A~OVE RECEIVED FROM: AT~S ~IRELINE NEG.'''~- SEPIA NEG. -..__.-- SEPIA NEG., _- SEPIA NEG, __--_. SEPIA NEG, .-____ SEPIA NEG. ~ SEPIA NEG, .___..__ SEPIA NEG. __..__._. SEPIA DATE ~ 19..~/ ,., Post-ItTM brand fax transmittal memo 7671 l#ofpages · / May 10, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 W. F. Simpson Manager, Regulatory Affairs Shell Western E & P, Inc. 601 W. 5th Ave., Suite 800 Anchorage, AK 99501 Re: Well No. Middle GrOUnd Shoal C21A-23 Shell Western E & P, Inc. Permit No. 91-44 Sur. Loc. 509'FSL, 1532'FEL, Sec. 23, T8N, R13W, SM Btmhole Loc. 219'FSL, 2845'FEL, Sec. 14, TSN, R13W, SM Dear Mr. Simpson: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. Sincerely, hairman Alaska 0~~.~ Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Shel May 10, 1991 Alaska Oil and Gas Conservation Col 3001 POrcupine Drive Anchorage, Alaska 99501 Gentlemen' SUBJECT' SUBMISSION OF REVISED VEl Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 ~mission ISION OF APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOA~ WELL NO. C21A-23 Enclosed in triplicate is the revi ed version of the Application for Permit to Drill the next well at kick off from well Cll-23 at appro> the surface location of Cll-23 of Conductor 27 was previously used f to abandon the well was submitted currently scheduled to spud on May ddle Ground Shoal. This well is a :imately 7800~. C21A-23 will replace 'latform C, Leg 4, Conductor 27. ~r well C43-23, for which the permit ecember 27, 1990. C21A-23 is 15, 1991. In the unlikely event that H2S is encountered, we intend to comply with 20 AAC 25.065 and follow the "Recommended Practices for Conducting Oil and Gas Production Operations Involving Hydrogen Sulfide." Please note that C21A-23 replaces C 1-23 as the fourth producer in the governmental quarter section. SWEP requests a variance by way of Administrative Approval (Rule 6), f'om Rule 1 of Conservation Order #44. The current well plan calls for a to maintain the flexibility to dri 11,000'. If you have any questions regarding Murnan at (907) 263-9614. Very Truly. Yours, Id. [o Manager Regulatory Affairs Alaska Division ID of 10,012', but SWEPI would like 1 to a maximum prognosed TVD of this report, please contact Susan WFS/slm Enclosures MISC\PERMIT ~ ~/-~1 ~- UI- ALA6KA ALASKA,?'~'~' AND GAS CONSERVATION ~""'"IMISSION PERMIT' TO DRILL" 20 AAC 25.005 la. Type of work Drill [] Redrill I~l lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepenr-]I Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of operator 5. Datum Elevation (DF or KB) 10. Field and Pool Shell Western E & P, Inc. 105 KB feet E, F, & G Pools 3. Address ....... 6. P~o, eJ'ty,Des, i, QrJ~Jon ~nn 601 W.. 5th Ave Suite 800 Anchorage, AK ' ' 99501' Mi ddl' e~rlro'uln~/~lo~a 1 4. Location of well at surface P1 atform C, Leg 4, 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) Conductor 27, 509'FSL, 1532'FEL of Sec. 23, Blanket At top of productive interval T8N,R13W,A. S. P 8. Well nurpber 'Number 344'FNL & 3701'FEL of Sec.23,T8N,R13W,A.S.P. C21A-23 400 HM7522 At totai depth 219'FSL & 2845'FEL of Sec. 14, !9. Approximate spud date Amount T8N, R13W, A.S.P. 5/15/91 $200,000.00 12.' Distar~ce to nearest 13. Distance to near~st well ":14. Number of acres in property 15. Proposed depth (MD and TVD) property line 5299 feet 972 feet 3746 10,025 & 12,683 feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Kickoff depth 7800 feet Maximum hole angle 50 * Maximum surface 1592 pstg At total depth (TVD) 5196 , , 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) .... 17-1/2"13~3/8" 54.5 K-55 BTC 1143R' 0 0 14.~R' 1434' 300sx '"G'i' + additives '12-1/4" 9-5/8"17&43.."L-80 LTC 9847' 0 0 9,847' 8145' 360sx "G" + additives i , NOTE: 13-3/6!" and 9-5/8" alrea, ly in Pi ace 1.8-1/2" 7" .~6 & 32]L-80& LTC 3591' 9092". 12~68: ' ],410sx "G" + additives P-1 :0 ., 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13,092 feet Plugs (measured) . true vertical 11,242 feet ' Effective depth: measured 9392 feet Junk (measured) ( proposed ) true vertical 7800 feet ,~~.,:.~.,.v,.,.~--;;":';' ;~'i :, Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor(in place) 360' 24" Ground To Surface 360' 360' Surface(in place) 1438' 13-3/8" 300sx "G" + Add. 1438' 1434' Intermediate(in place) 9847' 9-5/8" 360sx "G" + Add. 9847' 8145' Production Liner 3591' 7" 1410sx "G" + Add. 12,683' 10,025' Perforation depth: measured NONE true vertical 20. Attachments Filing fee' '~ Property plat BOP Sketch I~ Diverter Sketch ~ Drilling program I~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] ., 2.~?1 hereby certify that t~true and correct to the best of my knowledge 511~ Signed ~ "-"'- /--. Title Manager, Regulato,,ry Affai,,rs Date5/10/91 ¢,' commission Use Only Permit Number I APl number I Approval date See cover letter Oil- ¥~/ ' I 50-- '/,_t3-'.~ol~.? -O/_ ] ~) _,/_¢/.. for other requirements Con~litio[3,~ of approval Sarnples~d [] Yes J~ No Mud Icg'required [] Yes I~ No Hydrogen sulfide measures [].Yes ,[~ No Directional survey required ~ Yes [] No Required working pressure for BOPE .... []2M; [] 3M; I~ 5M; [] 10M; [~ 15M Other:~ ~, by order of /__ Approv~l~ ~..~....~.~~ Commissioner the commission Date , Form 10-401Rev.'~-- CAPACITIES: DESCRIPTION 16" HOLE (EST) 9-5/8" 47~ CS6 3-1/2" 9.3# 5" 19.5~ ANNULAR CAPACITIES: DESCRIPTION 16" OH x 3-1/2" 9-5/8" 47~ x 3-1/2" 16" OH x 5' 9-5/8' 47~ x 5" CF/FT BBL/FT 1.39626 0.24867 0.41102 0.07320 0.04883 0.00870 0.09972 0.01776 CF/FT BBL/FT 1.32945 0.23678 0.34421 0.06130 1.25991 0.22439 0.27467 0.04892 -.'J* - a ~" .~. . . . uJ W ,_-----,, ATTACHMENT IV '"C'"' ' PLATFORM · C21A-23 Magnetic Declination = 23.7°(23°42'] Grid Correction = 1.3°(1°18'] Net Magnetic Survey Correction=25.0°[25°00') Surface Location Leg 4, Conductor 27 ?/ 7500 8000 8500 · · 9O0O PLAN VIEW VERTICAL SECTION VSEC AZ=39.5° TARGET ~2 100' X 300' TARGE 50.' X.._250' ORIENTED CENTERED 9105' TV[ 55OO 9500 10000 10500 0 CENTERED ON: - ~ -~ ~' 9905' TVO ,~ · 4931" N ;- -- - -~ N 16°E ~ ~ ) ~ ~ 2169' W ~ 4000 ~'KOP if fl IIll - ~ III - ~ I I I "V~CAL SECTION 5000 4500 4427' N ~ · /i ~ ~ : ""~'"' _ r ; ' I I I'- i ;i ,/" , ; ;- 3500 ,KOP 7800' TVD - i i ~ ~ , i i I I i ~ KOP · - Z I fir ~ !! I ~ I I I ~ I I - 3000 \ [111 ~ I I - . ,~.l III [ I I : · "VERTICAL SECTION ' ~. ~. t ! I I I I ii ] I i~ 2500 · \~. ; ' ' , [ 2000 ~. \ 3000 2000 1000 " DEPARTURE TARGET -~ 1 \ VERTICAL SECTION 9105' TVD ~.~ TIE-IN COORDINATES AT 11303' MD ~. KOP: 2879' W 3249' N , , TARGET ~2 '~ · ' 9905. TVD 12503' MD ~ T D ' 10025' TVD ' ' 12683' MD 000 500 1000 1500 2000 2500 VERTICAL SECTION 5/09/91 DF-600-21A23 . .,_ASKA DIVISION DRILLING PROGNOSIS 4/20/91 WELL: C21A-23 LOCATION: PLATFORM 'C', LEG 4, CONDUCTOR 27 OBJECTIVE: HEMLOCK EVA LU ATIO N GEO LO GY ELEC. MUD SIGNIFICANT CORES SURVEYS LOGGER FORMATIONS O O 24' Conductor 13-3/8' Surface Casing Window milled in 9-s/8" HC HZ 7' Prod. Liner (TD) 1434= 7800! WELL CASING DEPTH AND TVD MD CEMENT '""Ii- I 438" ! · 9392' -, 'gl05' 11303' ' 9905' 12503' 10025' 12683' INTEREST: 66.67% AFE NO: 269071 FIELD: MGS EST. ELEVATION: 105' Cmean Iow Iow t~cle: 73'} DRILLING , HOLE SIZE HOLE DEV. AND DIR. CONTROL MUD PROGRAM 8-t/2' REUSED FROM Cll-23 i i 0F-600-2 1 A23 WELL LOC~TION PLAT MIDDLE GFIOUND SHOAL FIELD COOK INLET, ALASKA WELL: C21A-23 ! FASE NO.: ADL18756 PROPOSED LOCATION AT TOP OF OBJECTIVE: 245 FT. FROM N UNE AND 3629 FF. FROM SECTION 23, T 8 N~ R 13 W A.S.P. PROPOSED LOCATION AT TOTAL DEPTH: 355 FT. FROM S UNE AND 2853 FT. FROM SECT1ON 14, T 8 N, R 13 W A.S.P. E UNE MGS00118.407 DRILLING PROGRAM MIDDLE GROUND SHOAL C21A-23 , . e Nipple up BOP stack. Test all connections, valves, rams kelly, standpipe and emergency valves to 5,000 psi. Test annular preventer to 3,500 psi. Test casing to 3,000 psi. All tests performed in accordance with AOGCC regul ati ons. Kick off at 7800' TVD. Drill 10' and perform leak off test. Directionally drill 8-1/2" hole to TD. Run wireline logs and casing caliper log. Run and cement 7", 26#, L-80 and 32#, P-110, LTC liner. Proceed with cased hole completion prognosis. RRW/021591. C21A-23 CASING DESIGN Casing Design Criteria ~.~ac Gradient Pressure Gradient Max Collapse Pressure Max Burst Pressure Projected Mud Weight 13-3/8- 0.57 psi/ft 0.467 psi/ft 670 psi (Full evacuation) ]214 psi (1/3 BHP @ 9-5/8" csg pt) 9.6 ppg 9-5/8" 0.79 psi/ft 0.467 psi/ft 3643 psi (Full evacuation) 3700 psi (Injection pressure) 9.6 ppg 0.571 psi/ft 10000 psi (Frac pressure) 10000 psi (Frac pressure) 9.8 ppg AC£UAL DESIGN CONDITION Size Depth ]3-3/8" 9-5/8" 0- 1438 ' MD 0 .- 1434 ' TVD 0 - 4450 ' MD 0 - 4000 ' TUD 4450 - 9269 ' MD 4000 - 7800 ' TVD Weight Grade/ · (ppf) Coupling 54.5 K-55 B'IX2 43.5 I,-80 LTC 47.0 L--80 LTC Buoyed Tension Collapse (lbs) (psi) 6'7,069 670 Burs t (ps i ) 1,214 301,874 1,868 3,700 125,854 3,643 3,700 Casing Rating / Design Factors Tens ion Col lapse Burs t (kips) (psi) (psi) 853 / 10+ 1131 / 1.69 2836 / 2.33 825 / 2.73 3706 / 1.98 6691 / 1.81 905 / 7.19 4806 / 1.32 6693 / 1.8~ .) 9027 - 100t-t- ' TVD 26.0 b-80 LTC 32.0 P--llO LTC 59,114 26,772 5,154 3,700 10,000 10,000 519 / 8.78 897 / 10+ 5302 / 1.03 7440 / 2.01 10659 / 1.07 12159 / 1.22 RRW/PROGCSG RECOMMENDED MUD PROGRAM C21A-23 8 1/2" HOLE Interval: 9,269~ to 12,754~ Mud Type: Freshwater dispersed lignosulfonate mud. Recommended Properties: * Weight: 9.3 to 9.8 ppg, or as required to combat waterflood pressure (11 ppg anticipated) * Funnel Viscosity - 40 to 45 sec/qt * Plastic Viscosity: 15-20 cp * Yield Point: 10-20 lb/lO0 sq ft *API Fluid Loss: 10 cc; 5 cc by HC * HTHP FL at 150°F: less than 20 cc; 10 cc by HC * pH: 9.5 t 10.5 * MBT: 15 to 25 RRW/021591. ~ CASING AND CEMENT PROGRAM C21A-23 Run 7", 26 and 32#, L-80 and P-110, LTC from 12,754~ to 300~ above the 9-5/8" window. Extend the liner to cover any excessive casing wear in the 9-5/8". See attached casing design criteria. Cement liner with Class "G" + retarder + defoamer + fluid loss agent for WL less than 100 cc @ 150°F as required (15.5 ppg, 5.3 gal/sk, 1.19 cf/sk). An estimated 1410 sx of cement will be required. RRW/021591. ~ '1/2' HOLE 5000 PSI' ACK TOP OF KELLY BUSHING ~ '& 1,40",~ TOP OF OERRICK FLOOR BOTTOM OF ROTARY BEAM DRILL NIPPLE FLOW LINE FILL UP LINE ~ [/I PREVENTER r~J BLIND RAM 5000 PSI PIPE RAM 5000 PSI ~~' ~ooo SPOOL 13-5~8' 5000 MAIN DECK 5000 PS! RIS~ FLANGE SPOOL, WELLHEAD ROOM FLOOR ~]~ 'W~ 9/10187 13-3/8'SOW X 13-5/8' 3000 PSI 'WF' HOUSING N.T.$. DF-600-135-87 NOTE: DIMENSIONS INCLUDE 1/2' GAP BETWEEN FLANGE SH'ELL MII~IMUM aUXILIARY EQUIPMENT REQUIREMENTS N1asTer corltrOi Wllrl l"tvOrll oressure reOUlaXlnQ valve. Unit remote control ~Ivclraullc ROP ooeratlna unit. ~Cee OelOW mr c]etall. · Kelly coc~s :~ L.)ooer ~ Lower ~-essure Ratine 5.000 Dsl · Kitty saver suO wl~n orotector ruDDer. · *n$1oe ~OP. SurTaCe tVOe. Tot eacrt size c]rllt oloe. ii i ·;utt ooemno oali valve 1or eaCrl size orlll oloe in use. · Laloetlecl crossover SUDS for each 01ffere.~t connection ~n c]rlti strlna. OPTIONAL AUXILIARY EQUIPMENT · CJrculatlncj ncaa for each s~ze Drill olde in use wltrt steel OlDe aha 61Miw~q~ts to reach siena OlDe connection. · tnslae 8OP -Oroo or Oownnole tvoe. CuD or plug tVI0e t~C)P tester w~tn spare seals. SHELL MINIMUM HYDRAULIC OPERATING UNIT SPECIFICATIONS Accumulator volume -- must De,var 1.c. :~mes the volume to make position cnancje on all Iqvc]raul- ~caltv operated units anti retain 1200 Dsc ~2C]0 os~ adore orecnarqe~ w~mout oumos. Pumo caoacitv to ootaln 200 osl adore accumulator orecnarge oressure in two 12) minutes or ~ess. while ClOSlna annular oreven~er aha ooen~na ChOKe ~ne valve. See Section 431. DOwer ?or Dumos -- ~. sources rec~u,reo - -'-,r.~.zectr~c or All A~r Ir~g air CllUS seoarate air tanKI - ~. ~umos reoulreo. bnes from ooeratln~, un~ to c30P units 5.000 psi Minimum Yiela :~ Seamless steel lines .90" minimum I.ID. ~ Seamless s:eel lines win ~ Hose Der Section 4.32 OOeratlnq, unit flulcls: Hvaraullc oil or SOluote Oil. All controls snail De clearly markea to snow unit ooeratea. BlJna Ram control to nave easily remove(] latc~ or c~uarcl. Sufficient oOttlecl nitrogen or other Dacx-uo storage system to equal accumulator caoaclt¥, manifoldecl to I:)v-oass accumulator ancl close FlOP directly. Alarm. or wsual mOlCator to snow when accumulator is shut off from oreventer$. sHELL MINIMUM MUD SYSTEM REQUIREMENTS Pumo stroke counters eacn oumo. 'OeQasser. Pit VOlume recorder win alarm. Flow line monitor.. OPTIONAL MUD SYSTEM EQUIPMENT Trio tank (with 6th mini Flow tine gas separator. ,I MI$~£LLANEOUS EQUIPMENT SPECIFICATIONS AND INSTALLATION INSTRUCTIONS 1. All connict~orri sh.lll I~l vwlola. IZUaCILKL llano)eD or ~mmon ClamO Of comMraote rating. 2. All fla~ Ihlll, H APl 6B or 6BX i~ rmq ~SKeIS snail ~e APl sic RX or BX. Do not r~use 8X rln~. Alsys use ~ .n~ Oel~ Jw most or~emw when ltlnMs are ~r~. 3. 0railing sU~is sha~ Oe tor~ 0r tor~ lng ~taea. Pioe soools not ice.laDle. 4 80P lllCK sn~)t 0e 0rK~ to suo~se or su.i01l SuDo~T 0V lurnOucKl~ tlnfl or roOs.( NO r~g~O connKt~ons. ~. All Ute viivfl Iflll~ ~e ~ulooK w~lfl nanowneets. ~ams s~ouIo ~&ve ~nuiilv ooerit~ Klm l~x~ng ex,ins,ohs (ex(enaea 0evona suOoasll rely tot use. 6. For tlnO r~ l~e ~st~ control sliuon I~ o~rll~n9 unfl s~lll be t~lK i1 grou~ I~lt I mm~mum ot S0' from TO InT~t~t ~t~ O~rlllOn Of T~e miuer con.ot un.. FOr Dilltorm ~ 0~rge rl~ ifil ~sler control stilton O~rltmq Ual ~v De on the r,q floor w.n Tile remote stilton t~atK so Unit is DrotKtK from the ~li area lng ~s m ~t;on 4.32 in lne ~hetl Wilt ContrOl Mtfluil. 8. ~nlrKzM Snel~ ~=e no con~t~on ~o ~smq ne~ s~oe ~uets excmt 0v Drain ot Shell. ~. One ~re set ot ram Ol~Ks for me 0rill O~M ;n use Iflll~ De KeOt on r~. 10. Aflv ~tlQflNfll Ot rl~ snoula De corrKT~ ;O Ivota unaue ~r ot Clllnq. I 1. F~r ~V vOlW Sflit~ 0e KeDS odin Or CI~. not in n~tral D~llOn. e)Vor 40~ll~C~Ole rD Wtll MA, Clflq W,hOUt ~r#l PiPe. , 8. 9. 10, SHELL WESTERN E&P INC. MIDDLE GROUND SHOAL FIELD PLATFORM 'C' CHOKE MANIFOLD 1. 3' 5 KSI LINES 2. CROSS 3' X 3' X 3' X 3' 5 KSI 3. CROSS 3' X 3' X 3' X 3', X 3' 5 KSI 4. 3' 5 KSI GATE VALVE 5. ADJUSTABLE MANUAL CHOKE - 3' 5 KSi 6. REMOTE OPERATED CHOKE- 2-9/16' 10KSI HYDRAULIC ADJUSTABLE PRESSURE GAGE 4' LINES MUD/GAS SEPARATOR 6' LINE TO MUD PITS INLET~ VENTED AT CPi TO MUD PITS DF-600-2 19-89 PLATFORM 'C' SOLIDS CONTROL I ,' I I .'°1111 OPEItAIING MODE - DlilLIING UNWEIGHTED MUD I)llll. LII'IG WEI~;IITEI) Mur) 1 IIIPPItlG t'tlJII I'l SI. tJ(:; GATES CLOSED DiE, G D. E, G E, F, C, G C. D. F FLOW ROHTING 1-2-3-4 -5 I -2-3-4-5 4 -5-2-3 I -2-3-4 SOLIDS E('~lJlt' I1',1 IJSi= SS, SS (;¢)MMI fll :; MAY WAN]' ii) ()1'1-11^ Iii ,1' 4' I'lJ[Ir,/ED OFI wlVlF..li'~lllLi) MIIIJ IJI. CtCilCK I I.O-1 Ifil: :) I I BRAND'[ -- OEGASSEI L1~1-10 I I _L I I All ,:,l~alizer5 /oxc:opl Irom pil I I,~ :/""~'t TOP E(JIIALI;/AI'IOfl ~ AGITA [OR f,I ellhur lop or boll¢)ln SHELL MINIMUM BOP STACK REQUIREMENTS .. Min. Min. ~No. Item I.D. Nominal I Flowline ' ' '7" 2 Fill u.p .Line 2" 3 Dr!!ling Nipple : 4 Annular Preventer _ 5 Two singie or one dual hydrualically operated rams 6 Drilling sl~ol with 2" and 3" min. outlets 7 Gate Valve 3 1/8" 8 Gate Valve Power Operated 3-1/8" g Line to choke manifold .... 3" -- 10 Gate Valve 2-1/16" , 11 Check Valve 2-1/16" 13 Casing SpOol ' 14 Valves Gate 1-13/16" i5 Compound Pressure Gauge connector i6 Control I~lug or va'lYe !.1,3/!6" i7 Kill line to rig mud pump manifold 2" = ,,,, , 18 2" X 2" X 2" cross _ , , *NOTE: Additional specifications for Air/Gas Service are given in Shell Well Control Manual, Appendix 6.18. A rotating head shall be DrovlQecJ on Air/Gas Service OPTIONAL ! 2 Wear flange or bore .prote'ct~ 19 Gate valve 20 Line to roadside connection 2" .... 21 Rotating blowout preventer 22 Gat~ ~alve power operated 6" ,, DRAWING & CHECK LIST 104A SHELL CLASS 5M SURFACE INSTALLATIONS NORMAL AIR/GAS * FOR AIR/GAS DRILLING CONFIGURATION A .ANNULAR PREVENTER BLIND RAM PIPE RAM Location optional SHELL MINIMUM AUXILIAR% ,IPMENT REQUIREMENTS J, Master control with Hydril pressure regulating valve. 4 unit remote controt ~EIII -- -- I~ I Ill Hydraulic BOP operating unit. See below for detail. . Kelly cocks I~I Upper [] Lower Pressure Ratin~j 5~000 psi , Kelly saver sub with protector rubber. , Inside BOP, surface type, for each size drill pipe. * Full opening ball valve for each size drill pipe in use. * Labelled crossover subs for each different connection in drill string. OPTIONAL AUXIMARY EQUIPMENT * Circulating head for each size drill pipe in use with steel pipe and Chiksan joints to reach stand pipe connection. . Inside BOP - Drop or downhole type. Cup or plug type BOP tester with spare seals. SHELL MINIMUM HYDRAULIC OPERATING UNIT. SPECIFICATIONS __ Accumulator volume -- must deliver 1.5 times the volume to make position change on all h~,draul- icailv operated units and retain 1200 psi (200 psi above precharge).without pumps. Pump capacity to obtain 200 psi above accumulator precharge pressure in two (2) minutes or less, while closing annular preventer and ol~ening choke line valve. See Section 4.31.. _ Power for pumps - 2 sources required - Air-Electric or All Air (rig air plus separate air tank) - 2 pumps recluired. Lines from operating unit to BOP units 5,000 psi Minimum Yield [] Seamless steel lines .90" minimum I.D. [] Seamless steel lines with Chiksan joints. [] Hose per Section 4.32 Operatin~j. unit fluids: Hydraulic oil or soluble oil. Ali controls shall be clearly marked to show unit operated. Blind Ram control to have easily removed latch or cjuard. Sufficient bottled nitrogen or other back-up storage system to e~luai accumulator capacity, manifolded to by-pas; accumulator and close BOP directly. Alarm, or visual indicator to show when accumulator is shut off from preventers. SHELL MINIMUM MUD SYSTEM REQUIREMENTS Pump stroke counters each pump. Dega_~_er. Pit volume recorder with alarm. Flow line monitor. OPTIONAL MUD SYSTEM EQUIPMENT Trip tank (with 6th man) Flow line gas separator. .. MISCELLANEOUS EQUIPMENT SPECIFICATION$ AND INSTALLATION INSTRUCTIONS 1. All connections shall be welded, studded, flanged or Cameron clamp of comparable rating. 2. All flanges shall be APl 6B or 6BX and ring gaskets sh. al! be APl steel RX or BX. Do not re-use BX rings. Alwavs use new rings below lower most preventer when flanges are parted. 3. Drilling spools shall be forged or forged and welded. Pipe spools not acceptable. 4. BOP stack shall be'----braced to subbase or suitable support by turnbuckled lines or rods. (No rigid connections.) 5. Ali gate valves Shai_.._[ be equipped with handwheels. Rams should have manually operated screw locking extensions (extendecl beyond subbase) reedy for use. 6. For land rigs the master control station and operating unit shall be located at ground level a minimum of 50' from the well. The remote station is to be located near the driller's position. Inoperative condition of the remote unit is not to interfere with operation of the master control unit. For platform and barge rigs the master control station and operating unit may be on the rig floor with the remote station located so that is protected from the well area and accessible from a logical evacuation route. Hydraulic lines may be high pressure hose provided they meet the require- ments in Section 4.32 in the Shell Well Control Manual. 7.. Housing and heating should De provided for accumulator, blowout preventers, choke manifold where conditions warrant. 8. Contractor shall make no connection to casing head side outlets excel=t by order~ of Shell. 9. One spare set of ram blocks for the drill pipe in use ah.all be kept on rigs. 10. Any misalignment of rig should be corrected to avoid undue wear of casing. 11. Four way valves shal___[I be kept open or closed, not in neutral positon. *Not al3piicab/e to we//servicing without drill I~ipe. 4.28.12 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 March 29,1991 ADMINISTRATIVE APPROVAL NO. 44.46 Re: The application of Shell Western E&P Inc. to drill, complete and produce the Middle Ground Shoal 18756 No. C21A-23 well in the Middle Ground Shoal Field. W. F. Simpson Manager, Regulatory Affairs Alaska Division Shell Western E&P Inc. 601 West Fifth Avenue, Suite 800 Anchorage, Alaska 99501 Dear Mr. Simpson: The referenced application was received on March 27, 1991. The Middle Ground Shoal No. C21A-23 well is in the steeply dipping west flank part of the reservoir and will replace Cl1-23 as the fourth producer in this governmental quarter section. The Alaska Oil and Gas Conservation Commission has reviewed the evidence available and hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 6 of Conservation Order No. 44. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 March 20, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF THE APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOAL WELL NO. C21A-23 Enclosed in triplicate is the Application for Permit to Drill the next well at Middle Ground Shoal. This well is a kick off from well C]1-23 at approximately 7800'. C21A-23 will replace the surface location o[ Cll-23 of Platform C, Leg 4, Conductor 27. Conductor 27 was previously used for well C43-23, for which the permit to abandon the well was submitted December 27, 1990. C21A-23 is currently scheduled to spud on May 15, 1991. In the unlikely event that H2S is encountered, we intend to comply with 20 AAC 25.065 and follow the "Recommended Practices for Conducting Oil and Gas Production Operations Involving Hydrogen Sulfide." Please note that C21A-23 replaces Cll-23 as the fourth producer in the governmental quarter section. SWEPI requests a variance by way of Administrative Approval (Rule 6), from Rule 1 of Conservation Order #44. The current well plan calls for a TVD of 10,012', but SWEPI would like to maintain the flexibility to drill to a maximum prognosed TVD of 11,000'. If you have any questions regarding this report, please contact Susan Murnan at (907) 263-9614. Very Truly Yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures MISC\PERMIT CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (3) Admin ~;~. %/3 ~/g; 9. [9 -thru1'3)' ' 10. (10 and 13) 12. 13. (4) Casg ~./~.~_/.~v, . . (14 thru 22) (5) OPE (23 thru 28) Lease & Well No. YES NO Company 1. Is the permit fee attached .......................................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ........... , ...... 4. 'Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... ~..' Will all casing give adequate safety in collapse, tension and burst.. /~p_ Is this well to be kicked off from an existing wellbore ............. ~. Is old wellbore abandonment procedure included on 10-403 ............ //~ Is adequate wellbore separation proposed ............................ /~ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~ Are necessary diagrams and descriptions of div:rtar_ar_J BOPE attached. ,~--4', Does BOPE have sufficient pressure rating - Test to ~~ psig .. /~ Does the choke manifold comply w/API RP-53 (May 84) .................. ~ Is the presence of H2S gas probable ................................. REMARKS o ~o (29 thru 31) rev: 11/30/90 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Additional POOL CLASS STATUS AREA NO. SHORE ~, /M~/v4;¢/~,Cf.¢~K Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX,' .. No special 'effort has been made to chronologically organize this category of information. Copyright 1987,1988,1989,1990,1991 By WESTERN ATLAS INTERNATIONAL, INC. Ail rights reserved. Tape Subfile 1 is type: LIS **** REEL HEADER **** 91/ S/ll **** TAPE HEADER **** 91/ 8/11 Tape Subfile: 1 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes RECEIVED Alaska 011 & ~a~ Cons. Comrntssio~ Anchorage Tape Subfile 2 is type: LIS **** FILE HEADER **** .001 CN WN FN COUN STAT FILE ORGANIZATION: : SHELL WESTERN EXP. & PRO : C 21A-23 : MIDDLE GROUND SHOAL : KENAI : ALASKA FILE 1: COMPOSITE PASS - AC,DLL 9100 - 12400 FILE 2 : DUAL LATEROLOG REPEAT SECTION RUN 1. FILE 3 : DUAL LATEROLOG REPEAT SECTION RUN 2. FILE 4 : AC REPEAT SECTION RUN 1. FILE 5 : AC REPEAT SECTION RUN 2. * FORMAT RECORD (TYPE# 64) Tape depth ID: F 16 Curves: Name Code Samples Units Size Length 1 AC 68 1 US/F 4 4 2 CAL 68 1 IN 4 4 3 CHT 68 1 LBF 4 4 4 GR 68 1 GAPI 4 4 5 GRAC 68 1 4 4 6 RD 68 1 OHMM 4 4 7 RMLL 68 1 OtiMM 4 4 8 RS 68 1 OHMM 4 4 9 SP 68 1 MV 4 4 10 SPD 68 1 F/MN 4 4 11 TlR1 68 1 US 4 4 12 TiR2 68 i US 4 4 13 T2R1 68 1 US 4 4 14 T2R2 68 1 US 4 4 15 TEMP 68 1 DEGF 4 4 16 TTEN 68 1 LBF 4 4 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 943 Tape File Start Depth = 12400.000000 Tape File End Depth = 9100.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 224418 datums Tape Subfile: 2 948 records... Minimum record length: 62 bytes Maximum record length: 958 bytes 64 Tape Subfile 3 is type: LIS **** FILE HEADER **** .002 CN : SHELL WESTERN EXP. & PRO WN : C21A-23 FN : MIDDLE GROUND SHOAL COUN : KENAI STAT : ALASKA FILE NO. 2 DUAL LATEROLOG RUN 1 11080 - 11410 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Code Samples Units Size Length 1 CAL 68 1 IN 4 4 2 CHT 68 1 LBF 4 4 3 ED 68 1 MV 4 4 4 ES 68 1 MV 4 4 5 GR 68 1 GAPI 4 4 6 ID 68 1 A 4 4 7 IS 68 1 A 4 4 8 RD 68 1 OHMM 4 4 9 RLML 68 1 OHMM 4 4 10 RMLL 68 1 OHMM 4 4 11 RNML 68 1 OHMM 4 4 12 RS 68 1 OHMM 4 4 13 SP 68 1 MV 4 4 14 SPD 68 1 F/MN 4 4 15 TEMP 68 1 DEGF 4 4 16 TEN 68 1 LBF 4 4 17 TTEN 68 1 LBF 4 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 95 Tape File Start Depth = 11410.000000 Tape File End Depth = 11080.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** Tape Subfile: 3 100 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 68 Tape Subfile 4 is type: LIS **** FILE HEADER **** .003 CN : SHELL WESTERN EXP. & PRO WN : C21A-23 FN : MIDDLE GROUND SHOAL COUN : KENAI STAT : ALASKA FILE NO. 3 DUAL LATEROLOG RUN 2 11310 - 11520 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Code Samples Units Size Length 1 AC 68 1 US/F 4 4 2 CAL 68 1 IN 4 4 3 CHT 68 1 LBF 4 4 4 ED 68 1 MV 4 4 5 GR 68 1 GAPI 4 4 6 ID 68 1 A 4 4 7 RD 68 1 OHMM 4 4 8 RMLL 68 1 OHMM 4 4 9 RS 68 1 OHMM 4 4 10 SP 68 1 MV 4 4 11 SPD 68 1 F/MN 4 4 12 TlR1 68 1 US 4 4 13 TlR2 68 1 US 4 4 14 T2R1 68 1 US 4 4 15 T2R2 68 1 US 4 4 16 TEMP 68 1 DEGF 4 4 17 TTEN 68 1 LBF 4 4 Total Data Records: 61 Tape File Start Depth = 11520.000000 Tape File End Depth = 11310.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 239557 datums Tape Subfile: 4 66 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes 68 Tape Subfile 5 is type: LIS **** FILE HEADER **** .004 CN WN FN COUN STAT : SHELL WESTERN EXP. & PRO : C21A-23 : MIDDLE GROUND SHOAL : KENAI : ALASKA FILE NO. 4 AC REPEAT SECTION RUN NO.1 11020 - 11380. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 18 Curves: Name Code Samples Units Size Length 1 AC 68 1 US/F 4 4 2 ACQ 68 1 DIM 4 4 3 CAL 68 1 IN 4 4 4 CHT 68 1 LBF 4 4 5 CILD 68 1 MMHO 4 4 6 GR 68 1 GAPI 4 4 7 PORA 68 1 % 4 4 8 RFOC 68 1 OHMM 4 4 9 RILD 68 1 OHMM 4 4 10 RILM 68 1 OHMM 4 4 11 SP 68 1 MV 4 4 12 SPD 68 1 F/MN 4 4 13 TlR1 68 1 US 4 4 14 TlR2 68 1 US 4 4 15 T2R1 68 1 US 4 4 16 T2R2 68 1 US 4 4 17 TEMP 68 1 DEGF 4 4 18 TTEN 68 1 LBF 4 4 * DATA RECORD (TYPE~ 0) 994 BYTES * Total Data Records: 111 Tape File Start Depth = 11380.000000 Tape File End Depth = 11020.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 51159 datums Tape Subfile: 5 116 records... Minimum record length: 62 bytes Maximum record length: 994 bytes 72 Tape Subfile 6 is type: LIS **** FILE HEADER **** .0O5 CN WN FN COUN STAT : SHELL WESTERN EXP. & PRO : C21A-23 : MIDDLE GROUND SHOAL : KENAI : ALASKA FILE NO. 5 AC REPEAT SECTION RUN NO.2 11320 - 11690. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Code Samples Units Size Length 1 AC 68 1 US/F 4 4 2 CAL 68 1 IN 4 4 3 CHT 68 1 LBF 4 4 4 ED 68 1 MV 4 4 5 GR 68 1 GAPI 4 4 6 ID 68 1 A 4 4 7 RD 68 1 OHMM 4 4 8 RS 68 1 OHMM 4 4 9 SP 68 1 MV 4 4 10 SPD 68 1 F/MN 4 4 11 TlR1 68 1 US 4 4 12 TlR2 68 1 US 4 4 13 T2R1 68 1 US 4 4 14 T2R2 68 1 US 4 4 15 TEMP 68 1 DEGF 4 4 16 TTEN 68 1 LBF 4 4 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 106 Tape File Start Depth = 11690.000000 Tape File End Depth = 11320.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 264735 datums Tape Subfile: 6 111 records... Minimum record length: 62 bytes Maximum record length: 958 bytes 64 Tape Subfile 7 is type: LIS **** TAPE TRAILER **** ~/ 8/~1 O1 **** REEL TRAILER **** 91/ 8/~ 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Sun 11 AUG 91 10:26p Elapsed execution time = 1 minute , 13.4 seconds. SYSTEM RETURN CODE = 0
