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Home My WebLink About170-060PLGGING & LOCATION CLEARANCE REPORT State of ~_lask'a m~z~ O~L · ~s CONS~.aVAT~O~ C~SS~O~ PTD No. 7d'O60 Lease /Co2jZF0 Memorandum To File: API No. Well Name ~ .. ~u~,%k ~/~,'~ =r Opera tot Location Spud: . //0¢/7! , TD: /6;07? , Note casing size, wt, depth, cmt vol, & procedure. ~bnd Date Completed Review the well file, and comment on plugging, well head status, and lOcation clearance- provide loc. clear, code. '' /, I -- ' I- '~ Well head cut off: Marker post o= plate: Location ClearanCe: Code ~ Signed .~/~ ~~~ Date . ///~ /~ ~ · em a2 A\gen\lo-ap£m, zevS/24/95 DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF SPILL PRE~,~NTION .~Nq) RESPONSE Indust~' Preparedness and Pipeline Program TONY KNOWLE$, GOVERNOR 555 Cordova St. Anchorage. AK 99501 Phone t907)-269-7679 Fax (907~-269-7649 November-, 1995 Letter No.' 95-8-JR.BPX File No' .300.1q Mr. Steven D. Tavlor BP Exr)loration (Alaska') Inc. P.O. Box ~,96612 Anchorage. ,x_K 99519-6612 Re: Approval for Closure Inactive Drilling Waste Disposal Sites Dear Mr. Tavior: The Alaska Department of Environmental Conservation (.~)EC) has received correspondence from Mr. Dave Lowe. dated January. "" . .... 1995 concerning a recent list of inactive reserve pit closures. The list was addressed to your office and dated January. I2. 1995. Four sites were inadvertently omitted bv .&DEC from the list of closure approvals, and two additional omissions were identified by me Department while reviewing Mr. Lowe's letter. Furthermore. four sites received conditional closure status contmaent ur)on surface rehabilitation: three other locations were mentioned as candidates for further remedial action. Surface work is complete or in ?ro~ess at these latter sites and their status is now subject to further review by the Department. This correspondence describes our review procedures, puts forward the Department's f'mdings, and takes action upon the closure requests. The sites have been reviewed in accordance with the ,&DEC Interim Site Assessment Guidance for Inactive Drilling Waste Sites. June !991. The third draft of Alaska's new Solid Waste Regulations, 18 AAC 60. i,s currently under review, and this third draft contains a chapter on Inactive Reserve Pit closures. The closure criteria m this proposed re_milation parallels the closure criteria in the 1991 Guidance Document. Closure under the 1991 Guidance Document should constitute closure under the proposed Solid Waste Re_milations. The review procedures include an evaluation of the risk screemn_~ assessment reauired in the 1991 Guidance Document. and is summarized in our previous correspondence (January 12. 1995'). Briefly. the si~_cmificance of risk to local receptors is evaluated through study of contaminant release, exposure criteria, and consecluence criteria. Mr. Steven D. Tavlor BPXA Inactive Drilling Waste Disr)oSai Faciiitw Closure Approval November ~ 1995 SITES CONSIDERED FOR CLOSURE Based UDOn criteria from the June i991 INTERLM SITE ASSESSMENT GUIDANCE FOR iNACT~;E DRILLING WASTE SITES. the locations listed below have been reviewed for closure. The following sL'4 sites were omitted from the original list of closure requests' East Un'nat #1 East Umiat #2 East Ugnu umt #1 Sa~ Delta x i- 10- Sa2 Delta x 1-11 Reindeer Island The following seven sires ,- ~' ~ ' ~ · e~e,'~ e~ conciitionai closure sums contm_~ent ur)on surface rehabiiitation Shale Wail Umt ~'I si-02,7- Kermk Urnt r¢l ?o. Kur)aruk umt i & lA ir. killLk umt No. ' Fm Creek Unit No. Sa~ Delta Unit No. Sa~ Delta Unit No. 2 10-1i-16 Consideration of these sims for ciosure approval has been based (1) on a review of the suomitted inactive drilling .waste sim assessment documents listed below bv the ADEC Solid Waste, Water Quality and Contaminated Site Staff. and (~ site visits bv ADEC. ADNR. and ADF&G staff during Jutv of 1995 along with the resultant recommended remedial actions by the Der)artment undertaken at a certain number of these sites. Title: Inactive Rese,we Pit Pro2ram. Assessment anci Closure Supporting Documents: BPXA Video-documentation of Pit Closure:Site Restoranon Comparative Analvsis of Soil and Water Samples Submitting Person: Dave Lowe. BP Exploration (Alaska) Covered Facilities: Above Name Facilities Synopsis of Closure Procedure: Closed as is. No further action is needed for the drilling, waste facilities at these sites, except as noted below. *ir. Steven D. Tavior BPXA Inactive Drilling Waste Disr)osai Faciiitw Closure Approval November 7. 1995 CLOSURE A_PPROV.kLS The Deoarument's decision uoon ti~,e request 5or closure application submitted bv BP Exploration , Alaska~ Inc. is to approve for ciosure the beiow listed drilling waste disposal faciiities, effective October 25. ~995. This decision is supposed by ADNR and ADF&G: fine agencies a~ee with and e×oress no concern wire ciosure of the sites. Upon review of the submitted sample results required under the 1991 Guidance. certain remote sites exhibited metal concentrations and hydrocarbons m tine reserve mt surface waters and down zradient waters in excess of the Alaska Drinking Water Stanciards and Alaska Water Qualit?' Criteria (AWQC). While there is a basis for concern for those sites where exceedances occurred, there is also neziizible risk, and any corrective action warranted at these remote sites would not be required, realizing that the impact ~orre~,,ve ac=ion would be much areater than the benefits received. These sites, for the most part. have revegetate~i and any corrective measures would impact the established plant species at ~ese locations. These sites are 'Closed As Is' There are certain sites where corrective action is warranted, and 'Conditional Closure' is granted, pr>vialed the corrective action ~tir~uiations are comr)iete~ to t2e Der~arument's satisfaction. CLOSED .&$ IS East Umiat Unit #1 East Umiat Unit #2 Reindeer Island gl Fin Creek Unit 21 Itkillik Unit # 1 Kemik Unit 21 Kuparuk Unit 1 & lA Shale Wall Unit #1 Sag Delta 31-10-16 CONT)ITION.kLLY CLOSED These closure conditions were placed on the below-named sites following the site visiv'closure package evaluation: East Ugnu Unit #1 Remove trash and exposed portions of pilings. Push berms into reserve ~it. seed. and fertilize. Sag Delta 1 Reshape pad to natural contour and cover pit. Mr. Steven D. Taylor BPXA Inacta'e Drit~a--7--~-~-:'_ ~ ~Ai~,r~at Sag Delta 2 & 2A Reshape Dad to nan"a- ,, i----, 1~- TERMS AND C0~ These closure approvaisX~aa:~--. . Full Site Closure: The approval grant=t~_ ~" ' :-, ~-"--, a_-' ....-a-r'..'h,~_ wasze ximx ontv, as reauired under 18 A-kC 60.500 (& t"' a. - , '~ ~-a_,~t~__r:m.~ tx: caordinateci between the al. ownerlo~rator and~ ~ ~ , - i~--"~_~~_ ~-M3~KZL-q. or federal (BLaM) agency. Additionailv. shouifia~_ ~lu~,,_l~,~i~ si~kbe_ fiatnxi on the oad outside the drillin~ waste site ~--~ "----~ ~- "--:-~..~.;-- _u;,_ ia: ,r,ar~ to the ADEC Contaminated Sites Section (269-';iiilk New InfOrmation: Should additionai i,,i-.~c-- .... ~:.__, --:- ...... ..~ ctaxiifirmx ax tim facilit,,' make further actions ne~ssarv to ~ - ;- - ~--'-:--,-.~-,,,~~:tm Detainment reset'es the right to reouire additior~- - .... --, -.~ ',.',.;... o,- " ' at the facility. Dun' To Respond: Nothwitnstancimg a~_ j ,. -- ='--~ - -.- ,,,-. cg ~ ~ .x~provat. a oerson causing or perrmttmg me di _~-~--, ~,,_i.._ ~ is _re?:irr~ by law' to immediately contain and clean-u~~ If you haveanv furt~. 5 _.- office. 5_: ~_.= .--, cmmmz.~~m at 269-7679 of this G_ Mr. 5revert D. Taylor BP,'Cx. Inactive Drilling Waste Disposal Fa:iiiD, Closure Approval TC,,'JRC November 7, 1995 Dave Lowe. BPX/Anchora~e James Chatham. ADEC,?~nchora~_e AOG,~;Anchora_oe Nancy Welch. ADNILfFairbanks .Zd Ott. iM3F&G/Fairbanks Joe Saumer. ADEC/Ancnora~e Heather Stockard. ADEC,'Juneau Jim Havnes. ADNR/?znchora_~e Keith Mueller. USF~'S/.~chora_oe Jessie Kaieak Sr.. Mayor NSB;'Barrow ALAS~ OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 21, 1995 Land Department (MB 12-1) Pete Zseleczky, Manager BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, Alaska 99519-6612 Re.: Location Clearance, One Well Dear Mr. Zseleczky: On July 6, 1995 our representative visited one of your wells and conducted a Location Clearance inspection, with results as listed below. Insp. Date PTD No. Well Name and No. Condition July 6, 1995 70-060 Kemik No. 1 Acceptable Final Location Clearance is hereby approved for the above listed well. The Commission will require no additional work on it; however, BP Exploration (Alaska) Inc. is still liable if problems with the well occur in the future. Chairman cc: Blair Wondzell amlbpx95 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jeh~~n, Chairman DATE: July 6, 1995 THRU: Blair Wondzell, ~ F]].,E NO: P. I. Supervisor FROM: John Spaulding,~ SUBJECT: Petroleum Insp.?~-'- 199LGECD.doc Location Abandonment Kemik #1 PTD 70-060 BP Exploration Exploration Thursday July 6, 1995: I traveled via ERA Helicopter with Bob Gardiner Fairweather E&P representative to inspect the Kemik #1 well site. During the last winter season Fairweather plugged and abandoned the well and removed the well head and installed a plate with the legal description on the surface casing below grade as per AOGCC regulations. This well was drilled in 1970 and the area has grown up quite [Q (well with native grasses on the pad area and also in the pit area. The pit area was diked and lined, the lining has been removed and the dike have broaches in them so that run-off water will not stand. The portions of the pit area that remain blend in quite well with the surrounding terrain. In the area where the rig sub- structure was wood pilings were used for stabilizing the rig, these were cut off below grade originally and the frost has forced them up out of the ground about 12". To remove these pilings would cause damage to the re-vegetation process that is taking place, I feel these could be left in place. _ I recommend Kemik #1 for final surface abandonment. Summary: I inspected BPX's Kemik #1 exploration well for final surface abandonment. Attachments: 199LGECD.XLS Photos STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment I Location Clearance Report ( Title 20 AAC 25, Article 2 ) Operator: BP Exploration Address: FILE INFORMATION: ,, , , ,, , , Surface Location: F L, F L Section 17 ,T 1N ,R 20E ,M Umiat Well Name: Kemik #1 PTD No.' 70-060 APl No. 50- Unit or Lease Name: Exploration Field and Pool: Downhole P&A Date: Inspection Date': I 20 AAC 25.125 - ABANDONMENT MARKER: I Approval Date: Steel Post OD: (4" min) "Length (10' min.) ft. Height Above Final Grade Level (4' min.) ft. Top of Marker Post Closed With: (Welded, Cmt., Cap), Set: (On Wellhead, Csg, In Cmt) Distance Below Final Grade Level: ft. Side Outlets: All valves and nipples removed ? ~AII openings closed ? With Marker Plate Diameter: Marker Plate Attached To: Wellhead Information Beadwelded Directly to Marker Post or Blind Marker Plate: Operator: Well Name: Surface Location: F Section "Thickness: "Distance Below Final Grade Level: ft. Cutoff Csg Other , , , ( Note when different from file information) Unit / Lease Name: Remarks: L, F L ,T ,R ,M Inspection Date: 7/6/95 I 20 AAC 25.170 - LOCATION CLEANUP: I Approval Date: PITS: Filled In: yea Liners Removed or Buried: removed Debris Removed: SURFACE CONDITION OF PAD AND / OR LOCATION · rough with new vegetation growing in ( Rough, Smooth, Contoured, Flat, Compacted ) Clean: yes Type & Quan. of Debris if any remaining on pad and ! or location: none TYPE AND CONDITION OF SURROUNDING AREA' Hill tundra ( Wooded,Tundra,Grass, Brush, Dirt, Gravel,Sand) Clean: yes Type & Quan. of Debris if any remaining on surrounding area' none TYPE AND CONDITION OF ACCESS ROAD AND SURROUNDING AREA: gravel ( Dirt, Gravel, Ice, Other) Clean: yes Type & Quan. of Debris if any remaining on access road or surrounding area: road and airstrip have been re-vegetated and are doing quite well CLEANUP WORK REMAINING TO BE DONE: none (the area immediately adjacent to the well has wooden piling sticking up, this piling was cut off below grade when the well was abandoned and the frost action has pushed these pilings above ground about 12 to 18 inches ) To remove these pilings would cause problems to the area that is already growing in with native grasses. RECOMMENDED FOR APPROVAL OF ABANDONMENT: Distribution: Reason: orig - Well file c - Operator C - Database c- Inspector FI-O00 (Rev. 3/93) Yes yes No FINAL INSPECTION: Yes XXX No INSPECTED BY: John H. Spaulding 199LGECD.XLS ( If "No" See Reason ) DATE: 6-Jul-95 April 1, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATT: Blair Wondzell, Senior Petroleum Engineer Final Abandonment, BP Exploration (Alaska) Inc., Kemik Unit No. 1 Dear Mr. wondzell: Please find attached the following documents which are submitted to fulfil the reporting requirements for the above-referenced project. . , Two (2) originals: AOGCC Form 10-407. Two (2) copies: Summary of Operations for Final Abandonment, including photographic documentation of the abandonment. Two (2) sets: Daily Field Progress Reports covering on-site operations. The Kemik Unit No. 1 site will be re-visited in summer of 1995 as soon as the snow cover has melted. Final cleanup will be completed at that time. The AOGCC will be contacted when this work is complete so a site visit can be scheduled for your inspector. Please contact me if you have any questions. Sincerely, ~ R. C. Gardner President Attachments CC: Mark Stanley, BPXA Randy Thomas, BPXA Adrian Clark, BPXA Jesse Mohrbacher, Fairweather RECEIVED APR - 5 1995 Alaska 0il & Gas Cons. Commission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 ~ ~ ' STATE OF ALASKA ' · · ALASKA OiL AND GAS CONSERVATION COMM~USION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [~ SERVICE [] 2. Name (~f Operator 7. Permit Number BP EXPLORATION (ALASKA) INC. 70-60 3. Address 8. APl Number P.O. BOX 196612, ANCi~RAGE, ~K 99519-6612 50-~_23-20006 , , , ........... 4. Location of well at surface .'~------.-.-------i! "~~-~ 9. Unit or Lease Name 2396' WEL, 2073' NSL, Sec. 17, TIN, R20E, DM : ' TK~q~' KEMIK UNIT At Top Producing Interval 10. Well Number SAME AS ABOVE (straight hole) ~~ KEMIK UNIT ~ NO. At Total DepthL~i I 1. Field and Pool SAME AS ABOVE (straight hole) ,, , $i Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Exploratory 1234 ft. - original REB FAIRBANKS 021270. .......... 12. Date Spudded 13. Date T.O. Reached 14. Date Comp., Seep. or Aband. 15. Water Depth, il offshore I $6. No. o! Completions Jan. 1~ 1971 May 19~ 1972 June 17, 1972 N/A feet MSLI None 17:~gtal Depth (MD+T~D) 18.'Pl'ogBack Depth(MDI-TVD) 19. Directional Survey 20. OepH, wl;ere'~SSV set [ 21. Thickness of Perme(rost' m ...]_6,0.'/3' t4D.& ~L'VD 24.5' K]~ (t4I)& ~i/'D) YES [] NO ~ None fee.t MO I,.~g 1800 ~t. . m 22. Type Electric or Other Logs Run SCHLUMBERGER: DIL, DENSITY~GR, SONIC-GR~ C~L, DIPMETER 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157 "~BL SURFACE 72' 36" 154 SXS F~NDU ,, 20" 133 K-55 SURFACE 689' 26" 1470 SXS FONDU 13-3/8" 61 & 68 K-55 ~I~RFACE 2670' 17-1/2" 4270 SXS FONDU ...... .... 9-5/8" 47 8'-95/N-80 SURFACE 7708' 12-1/4" 1160 'SXS CLASS C + 150 ;XS CLASS G(2 STAGE...~ 7" 29 N-80 7341' 9158' 8-1/2" 550 SXS CLASS G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , , 8664, - 8800, _ 4SPF (1/2") NONE (ZSOLATED BY BRIDGE PLUG) :26. ACID, FRACTURE, CEMENT SOuE~ZE, ETC. DEPTH INTERVAL {MD) AMoUNt'& KIND OF MATERIAL USED ..... , , 27. PRODUCTION TEST Date First Production J Method of Operation {Flowing, gas lift, etc.} ~L~Y, 25, 1972] FLOWING " bate of Test ~o~rsTeSted ' ', PRODUCTION FOR IOIL.BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO JUNE ..1].~ 19~'2 24:5. TEST PERIOD I~ 0 ~'7,500 0 7/8"] (ALI, GAS) Flow:~DLng Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.2500 PS~, 0 24-HOUR RATE ~ 0 ~-10~000 0 NONE 28~ ..... C'ORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence o! oil, gas or water. Submit core chips. CORE NO. l: 862.2' - 8678'~ CUT 56'~ RECOVERED 56' (8622'-8638' SHALE; 8638'-8643' SHALE AND LIMESTONE, 8643'-8678' FRACTURED LIMESTONE- NO S~OWS) · CORE NO. 2: 10994' - 11,O~4', CUT 50', RECOVERED 50' APR - 5 1995 ...... ~ ~,,.~ llil & Gas Cons. Commission OB) Form 10407 RllCh0ra~i0;ubmi~ i. duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE .. ,. 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure dala, all Huld$ recovered and gravity, MEAS. OEPTH TRUE VERT. OEPTH GOR, and time of each pha~e. Okpik~ ;round level Shublik Fo~ation King~ Shale 2000' Measured DST No. 1 - Open hole test. Packer failed. Kemik Ss 2~20' ~pth & No. Test. Kingak ~ale 2510' T~e Vertical DST No. ~ - Open hole test. Packer failed. No. Test Kemik Ss 3587' approx~ately DST No. 2 - Open hole straddle test of inte~al King~ ~ale 3850' s~e - 8679' - 8719' Kemik Ss ~33' Depths are I~: 5060; I~ l& minutes, ~36 Kingak ~ale 4730' ~ ISIP 60 minutes, ~96; ~ 360 minutes 2022 Sag ~ver Ss ~>~ 8518' FSIP 60 minutes, ~96; F~ ~872 Shublik Li 8538 ' Saddlerochit. 8830' Est~ae 12 ~ CD from ~oke Data (d~ gas) Lisbu~e Li 10950' Recovered 210' slightly Kay~ ~968' gas cut ~d (pressures are psig) 31. LIST OF ATTACHMENTS 32. I hereby certil~ II,a~ Ihe Ioregoing i~ and corre~e,t el my knowledge ...... 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' Classi[ication of Service Wells: Gas injection, water injection, stemn 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 otlmrwise 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 term for each additional interval to be separately produced, showing tl~e 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 sl~ould 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 SUMMARY OF OPERATIONS FINAL ABANDONMENT BP EXPLORATION (ALASKA) INC. KEMIK UNIT NO. 1 The Kemik Unit No. 1 well was spudded on January 1, 1971, and suspended on June 17, 1992 after two seasons of drilling operations. The well was originally operated by Forest Oil Corporation, followed by SOHIO and finally, BP Exploration (Alaska) Inc. At the time the well was suspended, several downhole plugs were set and the producing horizon effectively abandoned. To facilitate reentry at a later date, no surface plug was set. The final abandonment work reported below consisted of: 1) setting a surface plug, 2) removal of the wellhead and cellar and the installation of a subsurface marker plate, and 3) general cleanupof the location and backhaul of solid and liquid wastes. A wellbore diagram is attached showing the post abandonment condition of the well. Mobilized equipment, materials and camp ;o Kemik Unit No. 1 location from Deadhorse using rolligon transport. Rigged up heated wellhead shelter and thawed wellhead. See Figure 1. . Nippled up and tested BOPE. Steam thawed wellbore to 150 ft. below ground level. Encountered restrictions in wellbore apparently due to collapsed casing. . Ran in hole with 2" steel pipe to set top plug. Could not get pipe past 80 ft. due to collapsed casing. Circulated water and cleaned out old mud. Mixed and set 80 sx 15.0 ppg permafrost cement plug from 80 ft. to surface. Took returns in vacuum tank. See Figure 2. . Rigged down wellhead shelter and excavated cellar to 12 ft below grade. Progressively cut windows in casing strings and removed cement in annuli. Noted evidence of collapsed casing 10 ft below grade. Cut off 13-3/8" casing and removed wellhead. See Figures 3 and 4. Welded marker plate on casing stub 10 ft below grade. Backfilled excavation and cleaned up location. See Figures 5 and 6. . Demobilized from Kemik Unit No. 1 location. Final site cleanup and inspection scheduled for Summer 1995 after snow has melted. Job completed with no lost time or OSHA reportable accidents. RECEIVED APR - 5 1995 l~tl.& Gas Cons. Commission , gnch0m;o ppg mud 30 in. shoe POST ABANDONMENT CONDITIO~I,x emik Unit: Well No. 1 Steel Marker Plate 72 ft 20 in. shoe 9-5/8 in. "disconnect" point Fluid x/o point 11.3 ppg rnud 9.8 ppg mud l OOsksClo~sOcml 9-5/8 in. bridge plug I 3-318 in. shoe 9-518 in. DY 1 I.I ppg mud Fluid x/o point 100 sks Class 6 cmt 7 in. liner top ! 80 ft. 689 ft 1790 ft lO00 ft All depths DRT 25'?6 rt 2,507 rt (togged) 2670 rt 27o7'.ft 6745 f't CMT 77176 f't '7339ft (togged) 9- 5/0 in. shoe 7700 ft I0.7 ppg mud 1234 fL RKB-MSL 14.4 fL RK'B-GL SO sko Class Gcmt 7 in. bridge plug 7 in. bridge plug Perforations 7 in. PDTD 7 in. shoe 150 oks Clo~ O cml 1 O0 sks Class O cmt 1 O0 3k3 Class 0 cmt 8- 1/Z in. TD 8,578 ft (togged) · ,. 8596 rt 8864- OOO0 ft 8863 ft ............ 9429 ft APR - 5 1995 Il I01 ft 13501 ft 160773 ft Alaska Oil & Gas Cons. Commission Anchors :o AF'! No. 50-223-20000 Permit No. 70-60 Spud: 1 / I/7 1 SuspenUed: 0/17/72 Figure 1. Rigging up wellhead she~ter and Installing Blowout Preventer Figure 2. View of wellhead after setting surface plug in 13-3/8~* casing. Note flow' nipple used for taking returns to vacuum tank during cementing. Figure 3. Breaking out cement behind 30*~ conductor during wellhead removal operations~ Figure 4. 30 inch, 20 inch and 13-3/8 inch casing stubs after wellhead removal. Note partly collapsed 9-5/8 inch casing. F~gure 5. Subsur~'ace marker plate welded on casing stubs at Kem~k Unit No. 1 ~ocatioa~ Figure 6. Backfilled and regraded location after well abandonment. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3-13-95 to 0600 Report No. 1 Date: 3-14-95 Job No. 008-01-200 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 hrs 3-14-95 Activity Report: Mobilized batch cementing unit, 7-1/16 inch double ram BOP stack, cement and other miscellaneous equipment to Deadhorse. Prepping camp, vac tanks, generators and other project equipment for shipment to Kemik Unit No. 1 location. Plan to commence mobilization f'rom Deadhorse to Kemik on Wednesday, March 15 with full work crew on location by Saturday, March 18. Fuel Used: 0 eal Weather ~ 0600 hrs: Temp: Pressure: 30.49 Chill Factor: -61 °F Fuel On Hand: 0 eal -51°F Wind: SW 5 kts Precipitation: None Submitted By: Visibility: 3/4 mile Sky: Ice Fog ~Fairweather E&P Services, Inc. RECEIVED ~PF~ - 5 1995 ~s~ u~ & Gas Cons. Commission Anchora FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3-14-95 to Report No. 2 Date: 3-15-95 Job No. 007-01-200 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 0600 hrs 3-15-95 Activity Report: Continuing with mobiliZation. Checked out vacuum tanks, 90 KW generator set, and materials shipped from Anchorage. Outfitted oil spill unit with sorbents and other response gear. Planning to move camp to Kemik location on Friday, 3/17, with remainder of equipment to follow on Saturday. Extreme weather conditions slowing progress of operations. Forecast is for improving conditions by Saturday, 3/18. Currently unable to fly aircraft due to ice fog and cold temperatures. ... APR - 5 1995 Fuel Used: 0 eal Weather ~ 0600 hrs: Temp: Pressure: 30.48 Chill Factor: -97°F Fuel On Hand: 0 eal -52°F Wind: W ~ 12 knots Precipitation: ...None Submitted By: Alaska 0il & Gas Cons. Commission gnchora,',~ Visibility: 1,5 mi - ice fog Sky: 800 ' overcast FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3-15-95 to 0600 Report No. 3 Date: 3-16-95 Job No. 007-01-200 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 hrs 3-16-95 Activity Report: Continue with mobilization. Continue rig up of 90KW generator for cementing/BOP unit and prep ofvac tanks for job. Plan to move equipment to Kemik Friday and through weekend with remainder of project personnel to follow late Sunday or Monday. Weather warming some and hope for continued improvement into weekend. .. APR - 5 1995 Fuel Used: 0 eal Fuel On Hand: 0 Mai Alaska Oil & Gas Cons. Commission Anchor~,.-',,' Weather ~ 0600 hrs: Temp: -40°F Wind: SW 12 knots Visibility: 6 mil¢~ Pressure: 30.22 Precipitation: None Sky: Clear, Light Ice Fog Chill Factor: -83 °F Submitted By: JesseMohrbacher 4 ~ Fairweather E&P Services, Inc. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3-16-95 to 0600 Report No. 4 Date: 3/17/95 Job No. 007-01-200 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 hrs 3-17-95 Activity Report: Continue with mobilization. HOok up sleepers, kitchen, water house and mechanic shop to camp generator for check out prior to load out. Camp check OK. Made up pipe running tools and slips at GBR welding shop. Checked cement mix with Halliburton lab. Cement mix tests very well, will need to add 0.12 lb/sx sodium citrate retarder to batch while mixing for 8 hour thickening time. First load out of equipment today with remainder to follow over weekend. APR - 5 1995 Fuel Used: 0 gal Fuel On Hand: 0 gal On-site Personnel: 0 0il & Gas Cons. Commission Anchorc '~ Weather ~ 0600 hrs: Temp: -22°F Wind: E 10 knots Pressure: 29.77 ~ Precipitation: Lt. Snow Visibility: 7 miles Sky: 3000 scattered Chill Factor: -53 °F Submitted By: Jesse Mohrbacher d~ ~ Fairweather E&P Services, Inc. FAIRW.EATHER E&P SERVI/"'"S, INC. FIELD PROGRESS REPORT ll~"h't No. Date: Job No. Al.rlg No. 684934 Contract No. 90JL235 CLIENT: PROJECT: Rel)ort Period: Activity Report: BP EXI LOIL&FION (ALASKA) INC. Kemik Unit No. I Final Abandonment Amendment No. 17 hiaska Oii'& ¢aS Cons. Cui-n,iiia~ion Anchort~-,~ Fuel Used" 7"',ff~ Fuel On Hand: ,ff,_5"~/:9 Wcather~ 0600 hfs: Teml,:-/~. Wind:~ Pres}ure'.~.$~ qx Precipitation' .~'/t, ,,_~'adg/.) Clliil Factor: -',~,~/~", Submitted By: Fairweathcr E& 1' Services, Inc. FAtRWEATHER E&P SERVI?~, INC. , FIELD PROGRESS REPORT R,:-%t No. Dal.e: Job No. AFE No. 00~ --o/-20O 6845)34 Conlract .No. 90J.b235 CLIENT: BP EXPLORATION (ALASKA) INC. Amendment No. 17 PROJECT: Kemik Unit No. 1 Final Abandonment n ~r'llll~l~ I~L~,LI V I.I,/ APR -5 1995 Alaska 0ii & Gas Cons. Commission Anchora: ~ Fuel 'Used' 7"80 Fuel On Hand: Weatl, e,'~ 0600 h,'s: Temp:-.,~9°~' Wind: Chill Factor:~. St, bmittcd By: Fairweather E&I' Services, Inc. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: (A ASI ) I C. Kemik Unit No. 1 Final Abandonment 0600 hrs 3-19-95 to 0600 Report No. 7 Date: 3-20-95 Job No. 007-01-200 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 hrs 3-20-95 Activity Report: Continue with mObilization. Load out 2 camp sleepers, oil spill unit, mechanic shop, Ce~nent, 6000 gal water and other miscellaneous equipment. Cat 225 backhoe, fuel and cementing unit to be loaded out later this morning. Expect approximately 12 hour travel time to Kemik now that the trail has been set. Remaining personnel will travel to Kemik later today or early Tuesday. APR -5 1995 Alasl<a Oil & Gas Cons. Commission Anchor~ :~ Fuel Used: TBD Fuel On Hand: 3500 mai Weather ~ 0600 hrs: Temp: Pressure: 29.71~ -27°F Wind: S 4 knots Precipitation: None , Visibility: 30 miles Sky: 9000 Thin scattered Chill Factor: -32°F. Submitted By: Jesse Mohrbacher/~,/~ / Fairweather E&P Services, Inc. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3-20-95 to 0600 Report No. 8 Date: 3/21/95 Job No. 007-01-200 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 hrs 3-21-95 Activity Report: Continue with mobilization. Load out Cat 225, DSR cementing/BOP unit, fuel, and miscellaneous equipment. Set up camp at location, prepare runway at airstrip, and prep location for remainder of equipment. Remaining crew and BPX representative plan to fly to location at 0900 hours today. RECEIVED Alaska Oil & Gas c.n,,~ ,,__ . l~nohore. ~ Fuel Used: TBD Fuel On Hand: 7000 gal Weather ~ 0600 hrs: Temp: -31 °F Wind: Pressure: 30.33 ~' Chill Factor: -83 °F On-site Personnel: SWE 18 knots Precipitation: Lt Snow 4 Visibility: 2 miles Sky: 600 f~, broken Submitted By: Jesse Motlrbacher ~ ~ Fairweather E&P Services, Inc. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3-21-95 to 0600 Report No. 9 Date: 3/22/95 Job No. 007-01-200 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 hrs 3-22-95 Activity Report: Complete mobilization. Load out steam unit, cement, 3000 gal water, two 2800 gal vac tanks, and additional miscellaneous equipment. Unable to fly remaining crew to location due to weather. Fairweather, DSR, and AIC (steamer) hands mobilized via rolligon. BPX representative to fly out to location later today. Activity at report time: Nippling up BOP rams for test. ,APR - 5 1995 Alaska Oil & Gas Cons. Commission Fuel Used: TBD Fuel On Hand: 7000 gal Weather ~ 0600 hrs: Temp: -°F Wind: Pressure: 30.53 Precipitation: None Chill Factor: -65 °F On-site Personnel: 12 SE 15 knots Visibility: 3/4 mile,blowing snow Sky: clear Submitted By: Jesse Mohrbacher ~ ~~ Fairweather E&P Services, Inc. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3/22/95 to Report No. 10 Date: 3/23/95 Job No. 007-01-200 AFE No. 684934 Contract No. 90JL235 Amendmeut No. 17 0600 hrs 3/23/95 Activity Report: Clear away snow and access timbers from wellhead area. Pig up wellhouse shelter and apply heat. Nipple up 7-1/16" 5000 psi BOP stack and test to 1500 psi. Test okay. Pig up steamer and ~ with steam hose. Activity at report time: Steam thawing wellbore at 50 ff. R Ff'I::IVi:h APR - 5 i995 ..... ,.,-o. CuI1]ITIJSSlOrl Anchorc Fuel Used: 4000 to date Weather ~ 0600 hrs' Temp: Pressure: 30.48 ~ ChillFactor: -52° F Fuel On Hand: 3000 gal On-site Personnel: 9 -25°F Wind: SW 10 knots Visibility: 20 miles Precipitation: None Sky: Clear Submitted By: Jesse Mohrbacher ~ y Fairweather E&P SerVices, Inc. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3/23/95 to Report No. Date: Job No. AFE No. Contract No. 11 3/24/95 007-02- 684934 90JL235 Amendment No. 17 0600 hrs Activity Report: Steam thaw wellbore to 150 ft. Close blind ram and prepare for cement job. 3/24/95 Activity at Report: Preparing to mix and set 150 ft. permafrost cement plug in 13-3/8" casing. RECEIVED ^laska Oil & Gas t;OmL AI'IChOr; '~ ............... Fuel Used: 400 gal Weather ~ 0600 hrs: Temp: Fuel On Hand: 2600 gal -13°F. Wind: SW 20 knots On-site Personnel: 9 Visibility: 1 mile Pressure: 30.32 steady Chill Factor: -56° F Precipitation: None Sky: Slight overcast Submitted By: Jesse Mohrbacher ,/~ T / Fairweather E&P Se~i~ces,~I~l;.' FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3/24/95 to Report No. 12 Date 3/25/95 Job No. 007-01-300 AFE NO. 684934 Contract No. 90JL235 Amendment No. 17 0600 hrs 3/25/95 Activity Report: Nipple 7-1/16" BOP stack. Observed evidence of collapsed casing at 20 feet in well. RIH with 2" pipe and met refusal at 80 feet due to apparent collapsed casing. Attempt to rotate through obstruction unsuccessful. Consulted with BPX representative and decided to set surface plug at 80 feet as per AOGCC approval in Sundry Notice. Circulate water to clean out old mud taking returns in vacuum tanks. Mix and set 80 sx 15.0 ppg permafrost cement plug. Cement in place at 1800 hoursl Rig down wellhouse and prepare to excavate cellar. Activity at Report Time: Fueling equipment and excavating cellar. Alaska Oil 8, Anchor~ Fuel Used: 450 gal Weather ~ 0600 hrs: Temp: Pressure: 30,62 Chill Factor: -15°F Fuel On Hand: 2150 gal -10°F Wind: SW 5 knots Precipitation: None On-site Personnel: 9 Visibility: 5 mile~ Sky: 3000 thin scattered Submitted By: JesseMohrbacher Se~~~es ~c.~' Fairweather E&P 'l ' FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hfs 3/25/95 to Report No. 13 Date: 3/26/95 Job No. 700--01-300 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 0600 hrs 3/26/95 , Activity Report: Excavate well cellar to 12 feet below grade. Cut off30" casing and break out cement between 30" and 20" casings. Cut out 3 foot 20" casing window to expose 13-3/8" casing. Evidence of collapsed 13-3/8" casing at 10 feet below grade. Cut off 13-3/8" casing and remove wellhead. Trim up casing stub and weld a 36" X 36" X 1/2" subsurface steel marker plate on 30" casing. Final plate elevation at 10 feet below grade and 5 feet below original ground level. Activity at Report Time: Backfilling cellar excavation and preparing to demob to ARCO Alaska, Inc. Kavik Unit No. 3 well. Expect a site visit from BPX environmental staff later today. APR - 5 1995 Alaska 0il & Gas Cons. Commission Fuel Used: 1000 aal Weather ~ 0600 hrs: Temp: Pressure: 30.79 ~' Chill Factor: -6° F Fuel On Hand: 1150 gal On-site Personnel: 9 -6 °F Wind: Calm Visibility: .....Unlimited Precipitation: None Sky: Clear , Submitted By: Jesse Mohrbacher _ q ~x~. Fairweather E&P Services, Inc. FAIRWEATHER E&P SERVICES, INC. FIELD PROGRESS REPORT CLIENT: PROJECT: Report Period: BP EXPLORATION (ALASKA) INC. Kemik Unit No. 1 Final Abandonment 0600 hrs 3/26/9 to Report No. 14 Date: 3/27/95 Job No. 700-01-300 & 400 AFE No. 684934 Contract No. 90JL235 Amendment No. 17 066 hrs 3/27/95 Activity Report: FINAL ACTIVITY REPORT. Backfill cellar excavation to original grade plus 10% to account for settling. Pick up miscellaneous debris on-site. Site visit by BPX Environmental Representative Dennis Riske went well. No environmental problems on location. Activity at Report Time: Moving off location to Kavik location. All equipment to be offKemik Unit No. 1 location by midnight tonight. Aircraft Incident Report: Forty Mile Air Helie Courier damaged on takeoff from Kemik location. Aircraft lost a ski on takeoff and damaged left side doors, windshield, and wheel strut. Passengers Jesse Mohrbacher, Don Fields,. Dennis Riske and pilot David Duke all uninjured and okay. Emergency landing made at Deadhorse airport with right wing touching runway and aircraft skidding to a stop. No injuries. Detailed incident report to follow.. Fuel Used: 665 gal Fuel On Hand: 485 gal Weather ~ 0600 hrs: Temp: 10°F Wind: Calm Pressure: 30.72 Precipitation: None ChillFactor: 10° F :. On-site Personnel: 6 Visibility: Unlimited Sky: Clear Submitted By: Jesse Mohrbacher ~ ~--~~ Fairweather E&P Services, Inc. RECEIVED APR - 5 1995 A!aska Oil & Gas Cons. Commission Anchor~"~ E. A. OPST & ASSOCIATES Geoscience · Engineering · Project Management 3500 Taiga Ddve (99516) P.O. Box 190754 Anchorage, Alaska 99519-0754 Telephone/Fax' (907) 345-6346 Commissioner Russell A. Douglass March 11, 1995 State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kemik Unit No. I P&A Dear Commissioner Douglass: ~COMM - .~ COMM RES. ENG <:~ SE ENG SE ENG ENG ASST I ENG ASST I SR'GEOL GEOL ASST{ !1 GEOL ASST~;f'i 'STAT TE~H, The BP Exploration Alaska (BPXA) Drilling Department has elected to abandon Kemik Unit 1 in accordance with the 150' surface plug provision of AAC 25,105. There appears to be considerable dissension concerning this decision and I suspect that the matter will be the subject of continuing discussions within BPXA. For your information and future reference, I have enclosed a copy of my correspondence file on the matter and I have nothing to add to what has already been said. I do want to thank you and your staff for your insightful consideration of this issue and I am certain that this effort will benefit future operations. Respectfully yours, E. A. OPSTAD & ASSOCIATES E~ik A/.~stad, BS, ~S, PG Enclosures RECEIVED MAR 1 4 1995 Alaska Oil & Gas Cons. Commission Anchora£;e CC: David Lowe, BPX w/o enclosures EAO:Im From: Date: Subject: To: Note for Wuestenfeld, Karen I Hirsh, Stu Fri, Jan 20, 1995 9:23 AM RE: Kemik #1 P&A Wuestenfeld, Karen FILE COPY Page Karen, ASRC owns the surface and minerals but I suspect that you will need permit approval from the North Slope Borough. . Stu From: Wuestenfeld, Karen on Fri, Jan 20, 1995 9'12 AM Subject: RE: Kemik #1 P&A To: Hirsh, Stu Stu, Fairweather is planning on setting up a camp within the leased area to support the P&A. We are trying to determine who needs to approve the surface use of the land during that_time. Can you let me know who needs to approve that use? From: Hirsh, Stu on Fri, Jan 20, 1995 7:43 AM Subject: Kemik #1 P&A To: Wuestenfeld, Karen Karen, The Kemik #1 was originally drilled on a federal lease F021270 issued by the BLM. However, this lease (and adjacent lease F021271) was conveyed to Arctic Slope Regional Corporation under provisions of ANCSA. If you need anything else, please let me know. Stu RECEIVED MAR 1 4 1995 Naska Oil & Gas Cons. Commission Anchora:,.;~ E. A. OPSTA & ASSOCIATES Geosdence · Engineering · Project Management 3500 Taiga Ddve (99516) P.O. Box 190754 Anchorage, Alaska 99519-0754 Telephone/Fax: (907) 345-6346 David Lowe Environment, MB 11-6 BP Exploration, Alaska P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kemik Unit No. 1 P&A Work Plan February 28, 1995 Dear Dave: To add detail to my previous comments, Commissioner Douglass indicated verbally that the Alaska Oil & Gas Conservation Commission (AOGCC) conceptually accepted my abandonment plan for Kemik Unit No. 1 and indicated that the Commission would likely grant a variance that would allow us to set a short cement plug in the very top of the 13-3/8' casing in variance to the 150' plug normally required under 20 AAC 25.105(i0. Naturally, we will still need to file a Form 403 detailing a specific work plan and submit that plan for AOGCC staff review and formal approval. Since the initial reaction of the AOGCC staff to our preliminary outline has been very positive, I'm confident that we can gain full approval in short order. This approach offers BP a number of advantages including: Iow cost, high personnel safety, Iow environmental risk, rapid execution and some positive precedents for future abandonment work in similar situations. I have the perception that the Drilling Department is already down the road on a much more involved project plan, but since no contracts have been signed, perhaps there is still time to reconsider. I've always felt that it is never too late to consider potential improvements in the logistics and safety of an operation, so even if we are not awarded this work, I urge BP to carefully reevaluate the various elements of the project. If there is anything I can do to help debate the merits of our proposal, please give me a call. Sincerely, E. A. OPSTA[;) & ASSOCIATES RECEIVED · a e MAR 1 4 1995 Alaska Oil & Gas Cons. Commission CC: BPX/Kemik/3Ltr.doc -- Anchora.::o MAR 01 From: Date: SubJeot: To: Cc: %: '95 01: iSPM Page Note for Lowe, David _ *** URGENT *** Lowe, David Wed, Mar 1, 1995 11:10 AM Kemik Unit #1 Abanonment Cost Reduction Stanley, Marie, Wuestenfcld, Karcn; Zseleczl~, Pete Platt, .~anet Pctc/lVlark, Before we make a final commitment on the contractor of choice for the Kemik Unit #1 Abandonment, I thought it would be worthwhile giving a brief outline showing the costs versus the benefits of the two alternate proposals, so a more informed decision could be made. We have two proposals. One from Fairweather, and one from E.A, Opstad and Associates. Fairweathcr $380,000 esdmate I~.A. Opstad $150,000 turn key fixed price .. F '..ai~eath.?. proposes_rnov'mg, . . equipment to the site with CATCO rollogons using Dcadhorse as mc starting pmnt. This as approximately a 75-80 mile journey rccuirine lithrs rolln~rnn .... " '~ -~,T: ---o travel ume each way. Patrwcather plans on a 8-9 man crew to steam thaw 150 of mud in the we~, remove the thaw_ed mud to storage tanks, ,then place 150' of permafrost cement as a surface plug. The well would then be cut off 4 below the surface, marked, then the hole hurler'flied with native material, They esfimat~ the program will take 7-10 days. E.A. Opstad. proposes using a much shorter travel path of 115 miles by beginning their trav.~,l at pump station I~2. This is a proven path along an old winter trail, and the same one used m the winter, of 1990 to remove all of the casing, fuel, unused mud products, and water pipe from the site. Their, abadonment plan is much simpler and theref6r~ less time consurnh{g and costly. They proposed to AOOCC.and gained their approval for using a Nodewell mounted or hand held ice auger to remove 10-15 feet of frozen mud from the casing and then backfill with permafrost cement. Thc well already has thre~ bridge plugs and cement plugs at depth to isolate the reservoir, so the only need for the surface plug is t,o prevent fluid movement into the well from the surface and to comply with AOGCC requtmments for a plug at the sttrface, AOOCC has approved.this plan and sees the merits of the more cost effective ?ai Proach, This program will take 3 days with about half the crecy the more complex rwca~her proposal uses. Using high temperature steam and removing boiling mud from the well bore into proper containment, poses much more risk to worker injury, and spills to the pads, than a simple a..uger removing frozen mud to a super sack. The volume of waste which will nccd to be disposed of will also be reduced with the auger plan to l/IS the volume removed from the well us, i. ng the .steam plan, Thc steam plan will also develop an addtional 3,000 gallons of waste dirty water that will have to be disposed of at thc ball mill. Total waste volume for thc steam removal approach will be approximately 100 Bbls. Waste disposal costs for tho steam approach will be $10,000, The auger approach'will generate about 2 bbls of frozen solid waste to be disposed of at a cost of $200. MAR 01 '95 Oi:iGPM 9075645020 P. 2x2 With the substantial cost differencc, reduced risk to wcn'kcrs, and reduccd risk of fuel end waste spills to the environment from less equipment and people .on site and no free hot liqttids bang tran~crrcd, ! think w0 must ..g!.ve. serious .consdiera.tton to, the .E.:A Opstad & Associates p .ropos~. This reduced cos_t will also go a long way ~owams gcrung cost recovery on thru project from Forrest Oil, We have several more well abandonmen~ coming up in the Sag Pdver Delta which will also ne, ed to be bid for closure, I thin~ it is important to reward innovative approaches to problem solving if we are to reduce our costs. The Fairweather work was given without consideration to other contractors. Clearly therc are more cost effective, safer, and more environmentally sound approaches that arc available if we encourage other possible vendors to bid on such work, In summary, the E.A. Opstad approach is safer, generates less waste, is faster, invloves less tundra travel and potential damage to the tundra, and is 39% of thc Feirwea~er cost resulting in a savings of $230,000, and a much greater likely hood of cost recovery from Formst OiL I will copy you both on copies of ,both proposals so you can make your own evaluation, I hope this review is helpful to you m making your d~cision. If there is anything e. lse I can do to help you control costs and reduce the environcmntal impact of this type of project please me know. Dave Low~ ~. O~ & (~as Cons. Commission ,, P~ch0ra~e M~R 0~ Frt~m: Date: SubJeot: To; '95 1A:$OPM g0756~5080 Note for Lowe, David L__ III Stanley, Mark Thu, Mar g, 1995 10:57 AM RE: Kemik #1 abandonment P. 1/2 Page Lows, David Dave, No not offended b~ ~ suggestions at all, whether its yourselves or the assets - there's mor~ md more interest m drilling's business these days md that's fine by me, as long as the accountability issue is clear. . We'd reco..gntzed the Pad.3 problem, CC-~, isn't n¢cccssafily a slam-dunk ezth.er, the ~ of'~he ltqmd waste is such that it should be easy for us to deal with. Solkl waste zs some~g that we need to work on, , l%l!.y aware of the Stewart Pet. incident and it was borne in mind by myself when initially &aling with th. ese folks. I don't want to start swapping stories hero but all I can Say is that in my own experience I have found them .knowledgeable of the issues (more so th~ Eric, although that is based on one conversation with him which I'm prepared to believe was not a true reflection of his technical capabilities ), they have demonstrat~ an excellent work ethic in really working the details that make for a safe operation and have shown no indication of a desn'e to short-cut the Regs. The prove is in the pudding and we shall see if I'm eating my words in a couple of weeks, if so, f'tre away, won't be the first or the last time that things don't go according to plan. Mark From: Lowe, David on Wed, Mar 8, 1995 6:4:5 PM Subject: RE: Kemik #1 abandonment To: Stanley, Mark Mark, I appreciate your concerns' but I wonder if you are confusfi~g price with quality service. If we really want experience, expertise, and a proven track record, why .am w.e. using Jesse Marbaeker, and Bob Oardner, the same two individuals who working for Bill Stewart in Cook Inlet side tracked a well without AOGCC well permits and got in trouble with ADEC for not reporti'n§ a spill they had at the site. Bill is in trouble with AOOCC and ADEC as a result of the bad advice he got from these two while they worked for ENSR last },ear. Their reputation is for taking short cuts and not working cooperatively or openly with regulatory agenCies, Call Dave lohnston with AOGCC and ask him who is more knowledgable and trust worthy - The Fairweather folks, or Erie. Remeber, Eric worked for us for years, played a major pan in PBU equity, drilled three new gas wells for the Barrow Oas field and installed the facilties, has drilled several new gas discoveries in Claifomia recently, and has entered a joint venture in Russia to develop a PBU size field in Siberia which is the subject of the next SPE meeting. His credentials are impeccable. Ask John Reeder our chief legal counsel about Eric. There is just no compar/son in teehincal knowledge, operational expertise, or ethical standards between F. tic and the Fairweather folks. Its your job and your decision, I just wanted you to be fully aware of all of the options available to you before you ~nade a con, mitre'tent. I ho~ you are not offended by my . suggestions which might have been a source of irritation. I too just want to make sur~ we do 12:51PM Page 2 the best work possible, limit pc~sonell, well, and environmental risk. This no~ is to you and you alone md not intended to ad~ fuel to the fire, but mal~ sure you are fully informed. I appreciate the chance to review the plans and your willingness to listen. One final comment on thc Fairweather plan is that you,need to direct them to udce the waste waigr and drilling muds to CC.2A not Pad 3 as stated m the plau. Pad 3.has no fldrd parry ballot agreemems which allow acceptance of this waste, plus the facility zs designed primarily for Class I waste, The waste from steam thawing will be a Class H waste and acceptable at CC-2A. Karcn Thomas can belp you line this up with the ball miR. Good luck with the project. Dave Lowc From: Stanley, Mark on Wed, Mar 8, 1995 10:35 AM Subject: Kemik. #1 abandonment To: Clark, Adrian; FarnSworth, Jim; Lowe, David; Thomas, Randy; Zseleczky, Pete Oenflcmen, Fatrweather presented the final version of thc operations plan to the AOGCC Monday af~m~n - no problems were raised by them and they indicated that a sign~ Sundry Approval would be in our hands by the end of the week. As. hoped, ARCO have confm'ned that they want to do the Kavik abandonment using Fan'weather/CATCO back-to-back with our operation. This is good news in that it reduces tho cost of Kemik #1 P&A by $66,000. (Down to $318,000). The likely mobilization date is around 13th M~rch (next Monday)- dependent upon weather conditions and CATCO o~her workload. Fairweather will be sending in daily repons to Randy/Adrian at 9.00am every morning. lust one more time I would like to put in writing that it is Drilling D. ept, who hav.e defined the scope of work based on our experience and good oilfield practic~ - tt ~s this pracuce that the gthencral public judge us against and there simply is no room for short-cuts when wc consider is operation vs. BPX's Alaska reputation. We consider the Fairwcathcr/CATCO to have bccn well planned with the right equipment being utilized and the personnel involved having experience in this type of operation with the right mix of skills. It provides us 'with the best opportunity of' conducting.Re opcradon with no accidents or environmental damage this is priority #1 for us. We are not adverse to new and innovative id~s for exploration location abandonment bu~ the correct placc to try these out is whcr~ the exposure to BP is minimal, This is not thc case here wh. exe wc arc operating very remotely and well intervention is required. The possibility exms, however unlikely, of trapped pressures/fluids being present that will rcqu~ knowledgeable personnel to act correctly if a envh~nmcntal disaster is not to occur. We would en_.courage a solicitation of a range of proposals from m~n~, contractors for standard locauon clean-ups ff the wells have been previously abandoned. For work where wen intcrvcmion is required and there is any doubt as to thc condition of the wellborc then personnel aud equipment must be used that we consider suffable for the task including the contingencies that wc have to consider. Mark InterOffice Memorandum E. A. Opstad & Associates Geosclence · Engineering o Project Management P.O. Box 190754, Anchorage, Alaska 99519-0754 Date: 03/12/95 To: From: Subject: Dave Lowe Erik A. Opstad~}~ Kemik Unit No. 1 P&A Telephone/Fax: 907/345-6346 Thanks for keeping me informed concerning BPXA's Kemik P&A plans and your discussions with Mark Stanley. I am not surprised at the outcome given the apparent circumstances, but I suspect that BPXA can benefit from this debate in the future if it chooses to. As one point of.clarification, over approximately 3 years in Barrow, using a light trailer mounted rig, we drilled 6 new wells, P&A'd 3 wells, worked over 2 wells, streamlined and modified the field processing facilities, laid several new flowlines with manifolds, and constructed solid waSte storage cells to generally rehabilitate the field. We continue to provide support to the Barrow Gas Field today! As you pointed out, this work is only one of numerous projects we have conducted worldwide over the past 20 years or so. For anyone to question our operational experience or :technical breadth they would need to be poorly informed at best! In any case, I appreciate the opportunity to submit a plan for the Kemik project, and please keep us in mind for other projects in the future. cc: Kemik File R. ECEIVED MAR 1 4 1995 N,sska Oil & Gas Cons. Commlsslon Anchora? Beep ' What Happened? -'t,~' I0 The Drillers "rejected" my plan. It was ....... too cost effective too safe too environmentally fdendly and the state liked it! ~ ._ I Yes.. not ~ one of their I typical Plans! Illl Maybe I should have added a helicopter... a Rollagon & a dozer or two?? · · I Mobilizing 22E would have been good! Obviously innovation has no rewards! ( E. A. OPSTAU & ASSOCIATES Geoscience · Engineering · Project Management 3500 Taiga Drive (99516) P.O. Box 190754 Anchorage, Alaska 99519-0754 Telephone/Fax' (907) 345-6346 David Lowe BP Exploration, Alaska P.O. Box 196612 Anchorage, Alaska 99519-0754 February 9, 1995 Re: Kemik Unit No. I Abandonment & Debris Removal Dear Dave: As you requested, i've put together an abbreviated workplan for the abandonment of the Kemik Unit Number 1 well and removal of debris remaining on the pad. Due to your time constraints, I wasn't able to provide a great amount of detail in the plan, but it should be adequate for your immediate purposes. I think that there is a better than even chance that the AOGCC will grant a variance to the surface plug requirements promulgated under 20 AAC 25.105(i0, which of course will significantly reduce the coSt of this operation. In the event that the AOGCC does not grant a variance, I also developed a cost estimate for a workplan that uses a small cable-tool rig to drill and cement the well per standing regulations. This budget is also included in Appendix I of the attached workP!an summary. Please let me know if you need any further information. Sincerely, E. A. OPSTAD & ASSOCIATES CC: BPX/Kemik/Ltr.doc EAO/mr WORK PLAN & PROPOSED BUDGET KEMIK UNIT NO. 1 WELL ABANDONMENT & DEBRIS REMOVAL Prepared for BP EXPLORATION ALASKA INC. P.O. Box 196612 Anchorage, Alaska 99519-6612 February 1995 E. A. Opstad & Associates · P.O. Box 190754 · Anchorage, Alaska 99519 · 907/345-6346 IKemik Unit No. I ell Abandonment ProposalI 1.0 SUMMARY The Kemik Unit is located approximately 30 miles east of the Trans-Alaska Pipeline System's (TAPS) Pump Station No. 2. The Unit's No. I well was spudded January 1, 1971 by Forest Oil Corporation and drilled to TD at 16, 073 feet to evaluate an anticlinorium comprising numerous thrust sheets. During the second season of operation, gas was discovered in a shallow portion of the hole. Referencing a RKB of 14.4', the hole was plugged back to 9158' MD and perforated between 8664' - 8780' MD. Drillstem testing produced 0.6 gravity gas at 10 MMCFPD from the Shublik Formation with an original reservoir pressure of 2678 psia. Following the drillstem test the well was suspended on June 17, 1972 by setting a series of 3 cement plugs plus 3 bridge plugs, with the shallowest cement plug set in the 9-5/8" casing at approximately 2335' MD. After backing off the 9-5/8" casing string at 1,798' MD, water based mud was left in the well to 55' and the well capped with 13-3/8" casing riser. Reports from recent site visits indicate that the well has since filled to surface with water, now frozen. Although the well has been thoroughly plugged, to meet the abandonment requirements stipulated by 20 AAC 25.105, the following remaining tasks must be completed: . "by displacement method, a cement plug at least 150 feet in length with the top of the plug 5 feet or less below rig grade elevation upland .... must be spaced within the smallest casing extending to surface" [20 AAC 25.105(i~)] . "Cements used for plugging within zones of permafrost must be designed to set before freezing and have a Iow heat of hydration." [20 AAC 25.105(j)] . Remove the wellhead and cut casing off 3 feet below the surface grade. Weld on subsurface identification plate. Remove cellar timbers and back-fill to grade. Pick-up any remaining debris. [20 AAC 25.170(a)] The above requirements are intended to isolate any subsurface hydrocarbons, protect fresh water resources from contamination, and leave the drillsite in a cleared, debris free condition; condition that will allow the area to return to its natural state. Although these regulations are typically closely adhered to, 20 AAC 25.105(m) does provide for variances with suitable and compelling justification. E. A. Opstad & Associates · P.O. Box 190754 · Anchorage · Alaska 99519 · 907/345-6346 Page 1 of 5 I Kemik Unit No. I V~'=,, Abandonment Proposal 2.0 WORKPLAN Given the location of the Kemik drillsite, our workplan intends to minimize personnel and equipment. Our pdmary plan is based on obtaining a variance from the AOGCC allowing the regulatory 150' cement surface plug to be reduce to a short 5' - 10' surface plug. We feel that such a vadance is likely to be granted in this case because: , . , , . The only perforated interval in the well is thoroughly isolated at depth by 3 cement plugs and 3 bridge plugs and in over 20 years has remained tightly sealed. The upper portion of the well is thoroughly plugged by perpetually frozen drilling mud down to the base permafrost at over 1,000 feet. Drilling the top off of a perfectly good plug of frozen drilling mud simply to replace it with a cement plug offers no practical increase in well security or fresh water protection. Installing a 150' cement plug can only be accomplished by mobilizing a considerable amount of heavy equipment, at significant cost, and with a real potential for damage to the delicate tundra environment. Our proposal to place a short cement plug at the top of the well will displace the near surface material that might melt in the summer, thereby maintaining a solid plug year round. This work and the other associated regulatory abandonment work can be accomplished with minimal equipment, personnel and environmental impact, while at the same time meeting the principal requirements of [20 AAC 25.105]. In preliminary discussions, the AOGCC has indicated that they see no immediate obstacle to granting such a variance, but would naturally need conduct a staff review of all the particulars of a formal variance request before issuing a ruling on the matter. In addition to filing a formal Variance Request. E. A. Opstad & Associates (OAA) would also obtain other required regulatory approvals and permits required for the job as direc~d,.pj/.,~.t~,l% We expect these to include: Kl: l:iV U · Application for Sundry Approvals, AOGCC Form 10-403 · Tundra Travel Permit (ADNR) UAR 1 4 1995 Alaska Oil & Gas Cons. Co~ Anch0ra~e A brief Well Abandonment Summary Report will also be prepared and submitted to BP Exploration that will document the job and final site condition. E. A. Opstad & Associates · P.O. Box 190754 · Anchorage · Alaska 99519 · 907/345-6346 Page 2 of 5 L,Kemik Unit No. 1 V~. Abandonment Proposat1 2.1 Operations Plan - The operations plan outline below assumes that a variance for the length of the cement surface plug will be granted by the AOGCC and that the field operation would be conducted during the first week of April 1995. 11. 12. Project Tasks 1. Obtain required regulatory permits an approvals. 2. Write Health, Safety and Environmental Plan. 3. Mobilize men and equipment to staging area near TAPS Pump Station No. 2 4. Conduct Safety Meeting & mobilize men and equipment to Kemik site. 5. Remove wellhead and cut-off casing 3 feet below grade (30", 20", 13-3/8'). 6. Drill out 13-3/8" casing and set Permafrost class cement plug. 7. Weld-on subsurface marker plate. Remove cellar timbers and rathole. 8. Inspect cellar area for contaminated soils or materials. Segregate same for future characterization and disposal. 9. Back-fill cellar to grade, 10. Pick-up any remaining debris on location and demobilize. File AOGCC Form 10-403 and submit Well Abandonment Summary Report to BP Exploration. Other duties as assigned by BP. We expect that the field operations can be completed in 3 days and that the entire project will span apProximately a week. BP oversight of the field operations will be at BP's discretion and expense. 2.2 Waste Disposal & Responsibility This plan will generate very little waste. Ice removed from the 13-3/8" casing will be melted and recycled for use in the cement slurry. Cement volumes will be carefully calculated to avoid any overage. Non-contaminated junk and debris remove from the Kemik site will be disposed of by OAA in Anchorage or Kenai at the city landfill upon demobilization. Any contaminated material or liquid waste that are segregated at the site will be remanded to BP and disposed at BP Exploration's expense. E. A. Opstad & Associates. P.O. Box 190754. Anchorage. Alaska 99519. 907/345-6346 Page 3 of 5 ! Kemik Unit No. 1 i~ .. Abandonment Proposal 2.3 Equipment & Personnel Requirements The OAA workplan will utilize the following major equipment to support the operation: 6-man camp (@ Pump Station 2 staging area). FN160 Nodwell Tracked Vehicle, 6-man cab, 16,000 lb. capacity. FN100 Nodwell Tracked Vehicle, 3-man cab, 10,000 lb. capacity. Nodwell Trailer. Pickup Support Truck. Flatbed Support Truck. Case 580 Loader/Backhoe w/Forks. 500 Gallon Fuel Tank. 2 Bbl Cement Tank/Mixer. 2" Slurry Pump. 3" Slurry Pump. Welder & Cutting Touches. 15 KW Generator. Space Heaters. Wellhead Shelter. Arctic Survival Gear. 10 Bbl Waste Tank & Solid Waste Drums. Spill Kit. Gas Detector. Lot Miscellaneous Hand & Power Tools. Lot, Chains, Cables, Slings, etc. Communications/Position/Navigation Gear. a) GPS Unit b) ELT c) Cellular Telephone This operation is expected to require a 6-man crew 3.0 PROJECT BUDGET The Budget and Terms for this workplan are provided in APpendix I and are based on the assumption that the AOGCC will grant a variance to 20 AAC 25.105(i~) and allow a short surface plug to be set in the 13-3/8 casing. Since there is a possibility that the AOGCC might not grant such a variance, we have also provided a budget that reflects setting a full 150 foot cement plug. This budget include mobilization of a small cable-tool rig, tanks and equipment as required to drill out the frozen drilling mud to a depth of approximately 160' BBH and place a continuous 150' permafrost cement plug. In the event that this conventional approach was dictated, additional details for this workplan would be provided. E. A. Opstad & Associates, P.O. Box 190754 · Anchorage, Alaska 99519 · 907/345-6346 Page 4 of 5 E & P SERV/OES, /NO. March 6, 1995 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Blair Wondzell, Senior Petroleum Engineer Final Abandonment, BP Exploration (Alaska) Inc. Kemik Unit No. 1 Gentlemen: Please find enclosed three copies of AOGCC Form 10-403 and supporting documentation covering the above-referenced work. We anticipate doing the work in mid March, 1995; therefore your timely review will be appreciated. Please contact the undersigned if you have any questions on our approach to this project. R. C. Gardner President Enclosures RCG/js CC: Mark Stanley, BPXA Jesse Mohrbacher, Fairweather RECEIVED MAR -8 lg95 Alaska 0ii & Gas Cons. Commission Anchora[~e 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 STATEOF ALASK^ . ~ "AL (' )ILAI,IDGASCOi'ISERVAI'iON COIvlMIS:> O~ APPL. I-C~ ~ON FOR SUNDRY APPR x/ALS 2_. I'lalne OI OperalOr .___B_p._F. Lxjploration (Alankn) lac. 3. ^dthess I' 0 Box ].96612~ Anchorage~ AK 99_519-6612 .I. [.coal/on OI ,.veil al sutlace 2396' gEL, 2073' NSI,, Sec. 17, TIN, K20E, UN Al lop ol ptoducliv~ inlet vol Same as above Al elleclive deplh Same as above Al Iolol deplh Same as above RECEIVED ~/~R - 8 1995 Alaska Oil & Gas Cons. Commissio~ Anchor~ ~' i;L Ple.'.oni v/ell coati/lion sumnl~lry 'rolal del)Ih: measured IrtJe veil/cai I;. I_)alu,n elev;dlorl (DF o~ KI:]) ].23/s' RKB - HSI.. 7. Ulfil el I)roi)c~l¥ name Kemik Un[l: I]. Well ilunlber ~.J. ['cl. lnil iiLiilll)el 70-60 it). AIH numbel 50~ 223-20006 I I. Field/Pool Wi.]Ldc.3t 16073 16073 leel Plugs (,neasumd) See .below leer Elleclive depll~: measmed l~ue verlical 8863' 8863' leel Ju, fl~ (,ncasu~ed) leel None Casing Lcnglh Slrucluial Conduclor 72 ' Sutl,3ce 689 ' Inleffnediale 2,670' Pioduclion 7,708 ' Liner 1,819 ' Pe~loralio[ldeplh: rllcasured 866t~' - 8800' true ve~lical 866~' - 8800' Tubing (size, grade, and recast, ed del)Ih) None Packe~s and SSSV (lypu and measured der)ilO None Size 30" 20" 13-3/8" 9-518" 7" Ce,,,er,led Ivleasu, ed deplll 'liue vmlical deplh 156 sx Fondu 72' 1670 sx Fondu 689' ~270 sx Fondu 2670' 1160 sX Class G + 1,798-7,708' 550 sx Class G B~end 7~339L9~158' 72' 689' 2670' 1,798-7,708' 7,339-9,~58' Plugs: (see attached veil schematic) 13,501' to~'--13~211' ]_lmlOl' to~---lOm811' 9,~29' to 9,158' (tagged) 9~]38' to 8~863' (tagged) BP @ 8~596' BP @ 8~578' w/cmt above to 8,311' 7~176' to~6,897' BP @ 2~587' 2~576' to~2~297' 13. iqtacl~mer~ls Oescriplion summa,y el prol)osal 7, Dela[ted Ol')eralions p, ogr;.u,I ._X_ BOP slmlch X__ 14. Eslimaled dale Io[ Commencing opel;dion March 1, 1995 16. II ploposal v/as vclbally approved Oil ~ OaS ~ Hame el aPl)rover i, Dale approved · Service ll. iherebyce, l,l'~helorr~goingialt~dcorrcclloll,,~beslol,,,Ylu,ov,.ledge. ' Sigr,e 'rifle ~l~i~ ~. ~F~'~. ' ' 0- Fu~uu,~f;ilouIul,/UoEoFIE, 13. $1alus el well classilicaliol~ SUsl)r;rlded X_~ AI)l)~oved by o, d,;r O[ I1,(: COHll original signed By David W. Johnston Approved Copy Returned Form IU.,I03 Rev OG/1510U SLJtlMI 1' IN I IIlI"LICAI E BP EXPLORATION (ALASKA)INC. KEMIK UNIT NO. 1 WELL ABANDONMENT APPLICATION FOR SUNDRY APPROVALS SUPPLEMENTAL INFORMATION REQUEST FOR REGULATION VARIANCE 20 AAC 25.170(a)(1)(3)(4) Onshore Location Clearance BP Exploration (Alaska) Inc. (BPX) hereby requests that the requirements of 20 AAC 25.170(a)(1)(3)(4) be waived with respect to the following Kemik Unit No. I location items: . Wood Piling: The remains of approximately 250 wood piling are present on the Kemik Unit No. I location, These piling were previously cut off below grade, but have reappeared due to frost jacking. Arctic Slope Regional Corporation (the landowner) and the Alaska Department of Environmental Conservation, both support leaving the piling in place rather than removing them by mechanical excavation, as removal would cause unwarranted environmental damage (see attached correspondence to BPX from ASRC and ADEC dated February 23, 1995 and March 1, 1995 respectively). , Reserve Pit: The Kemik Unit No. I reserve pit is bermed on all sides and breached on the northern side of the pit (see attached photo). This breach allows spring snow melt to run out of the pit and thus, standing water is eliminated. BPX conducted a revegetation program on the Kemik Unit No. I location and reserve pit in 1992 and both are revegetating well. Filling in of the remaining reserve pit will negatively impact ongoing revegetation of the drillsite. BPX has received a conditional closure approval from ADEC on this pit (see page 6, ADEC letter to BPX dated Jan. 12, 1995, attached). 20 AAC 25.105(h)(2) (i)(1) Plugging, Suspension and Abandonment of Wells BPX also requests a waiver to the requirements of 20 AAC 25.105(h)(2) and 20 AAC 25.105(i)(1) (if necessary) in accordance with the following conditions: . Casing Stub Plug at 1,798 ft.: Representatives from Fairweather E&P Services, Inc. met with Mr. Blair Wondzell, Mr. Robert Crandall, and Mr. Jack Hartz of the AOGCC on December 20, 1994, to discuss a possible variance to the requirements of 20 AAC 25.105(h)(2). The request was taken under consideration and then verbally approved provided that one of the following two stipulations could be met. If fluid level had not dropped more than 100 ft. from the original suspension level (55 ft. RKB), the downhole plug will not be required across the 9-5/8 inch casing stub. If the fluid level had dropped more than 100 ft. since the time of suspension, pressure test the 13-3/8 inch casing to 1,000 psi. If the casing held pressure, the downhole plug would not be required. RECF. IV rr.D Kemik Sundry Notice MAR - 8 1995 0ii & Gas Cons. Commission Anchor~'r-~ BP EXPLORATION (ALASKA), INC. KEMIK UNIT NO. 1 PTD 70-60/APl # 50-223-2006 PROPOSED WELL ABANDONMENT AND SITE CLEARANCE PROGRAM BACKGROUND AND SUMMARY OF PROPOSED WORK The Kemik Unit No. 1 well was spudded January 1, 1971 and suspended on June 17, 1972 after two seasons of drilling, operations. The well was originally operated by Forest Oil Corporation, followed by SOHIO and finally BP Exploration (Alaska), Inc. (BPX). The well was driilstem tested upon completion and flowed over 10 MMSCF per day from perforations at 8,664 to 8,780 ft. MD/TVD. At the time of suspension, several cement plugs were set downhole with the last plug at approximately 2,300 ft. inside the 9-5/8 inch casing. The 9-5/8 inch casing string was then backed off at 1,798 ft. and a 1/2 inch steel doughnut plate was bolted on top of the wellhead "B" section with a 6 ft. long 13-3/8 inch capped casing riser welded on top of the steel plate. Water based mud was left in the 13-3/8 inch casing. The drilling fluid level at the time the well was suspended was 55 ft. RKB. A January 6, 1995 site visit identified that the well has since filled up with water to form an ice plug to surface. This ice plug is probably continuous through the permafrost, which may be as deep as 1,800 ft. Attachment 1 is a weiibore diagram showing the current status of the well. All footage measurements are referenced to RKB (14.4 ft. above ground level). The Kemik location has undergone moderate thermokarsting since construction over twenty years ago. The wood timber well cellar is intact and approximately 250 wood piles remain on the location. The reserve pit area is partially bermed and slightly down gradient from the wellhead. In general, the site is clean and free of debris with the exception of the piling remaining on location. In order to abandon the well in accordance with current Alaska Oil and Gas Conservation Commission (AOGCC) regulations, it is necessary to complete the following tasks: 1. Set a 150 ft. surface cement plug inside the 13-3/8 inch casing. . Remove the wellhead, cellar and rathole; cut off the casing a minimum of 3 ft. below original ground level and install a subsurface marker plate. 3. Pick up any remaining debris on location. This work is required under 20 AAC 25.105(i)(1) and 20 AAC 25.170(a). Kemik Sundry Notice Gas Cons. Commission Although removal of approximately 250 wood piles from the surface is required by AOGCC regulations, BPX hereby requests a variance to this requirement as the Alaska Department of Environmental Conservation (ADEC) and Arctic Slope Regional Corporation (ASRC) have determined that piling removal will do more harm than benefit (see attached correspondence). BPX also requests a variance to the requirements of 20 AAC 25.105(h)(2)(A) which requires a cement plug across the 9-5~8 inch casing stub at 1,798 ft. This variance is requested because the January 6, 1995 site visit identified that the fluid level in the wellbore had not fallen below the level at the time of well suspension (55 ft.) and the well has no pressure at the surface. This well condition was an AOGCC stipulation for waiving the downhole plug requirement. Approval is requested for the following detailed operations program. Estimated starting date for the project is March 10, 1995 and the project is expected to take 8 to 10 days to complete. DETAILED OPERATIONS PROGRAM . Obtain all required permits and regulatory approvals before starting the job. Required permits include the following: Application for Sundry Approvals, Form 10-403 (AOGCC) Tundra Travel Permit (ADNR) Food Service Permit (ADEC) North Slope Borough Administrative Approval Arctic Slope Regional Corporation Letter of Non-Objection Ali permits will be held by BPX with the exception of the Tundra Travel Permit which is already held by CATCO and the Food Service Permit which will be held by the caterer. . Mobilize all required personnel and equipment to the Kemik location on an as needed basis. Transport equipment via CATCO units and personnel by helicopter or fixed wing aircraft. Set up 12 man camp and lined fuel containment area prior to beginning any site work. o Erect prefab shelter over wellhead and apply heat to shelter from hot air heater. Nipple up.and test 5,000 psi WP 7-1/16 inch BOP stack. (BOP's will consist of a double ram stack with blind and shear rams - see Attachment II). Test BOP stack to t,5_00 psi. RIH with 1 inch pipe and pump steam down 1 inch pipe until frozen ~ mud in 13-3/8 inch casing is thawed to 160 ft. below original ground level. In the event that refusal is met at a shallower depth due to junk or collapsed casing, BPX requests that the surface plug be set at whatever depth can be obtained in the event of refusal. ~ E ~ E ~V E ~l Kemik Sundry Notice ~/~R - 8 ]995 Gas Cons. Commission Anchor~: :¢' . . . . . o 10. Rig down BOP. Rig up top job cementing system and circulate the hole with water to clean up weilbore prior to cementing. Collect all waste fluids in a vacuum tank. Mix and set a 150 ft. permafrost cement top plug and have plug witnessed by AOGCC representative. Rig down wellhead shelter. Excavate cellar and area around wellhead to expose 30 inch conductor casing a minimum of 4 ft. below original tundra level. Segregate any contaminated soils/materials for sampling and proper disposal. Cut and remove 30 inch casing from exposed well. Break out cement behind 30 inch casing to expose 20 inch casing. Rig up safety line on wellhead to prevent wellhead from falling into the excavated area. Cut and remove 20 inch casing window and break out cement to expose 13-3/8 inch casing. Cut 13-3/8 inch casing and remove wellhead for backhaul. Trim up casing stubs to a minimum of 3 ft. below original ground level and weld a 36"x 36"x 1/2" subsurface steel marker plate onto the 30 inch conductor. Backfill excavation to existing grade. Attachment III shows the post abandonment wellbore condition. Pick up any remaining debris on location and demob remaining personnel and equipment to Deadhorse or to next assignment. File Report of Sundry Well Operations for the AOGCC. Return to Kemik location the following summer for final AOGCC inspection and to pick up any remaining debris. HEALTH, SAFETY, AND ENVIRONMENTAL PLAN BPX will prepare a Health, Safety, and Environmental Plan to cover potential occurrences such as diesel spills, MEDIVAC, personnel safety, wildlife encounters, cold weather operations, and other relevant issues. Safety meetings will be conducted prior to the start of the project and daily thereafter. Kemik Sundry Notice ~/XR - 8 't995 Gas Cons. Commission ATTACHMENT !'(I FAIRWEATHER E & P BOP STACK SCHEMATIC 7 1/16" 5000# LW$ Double BOP ......... 7 1/16", 5000# X 3000# Adapter Spool 7 1/16", 3000# X 13 5/8" 3000~ Single ~tudded Adapter 2 1/16" - 5000~ Gate Valve Below Bottom Rams Double Blind Rams /_ 26 2t4" r-7-] 11.2 ppg mud 30 in. shoe 20 in. shoe 9-5/8 in. "disconnect" point Fluid x/o point 11.3 ppg mud 9.8 ppg mud 1 O0 sks Class iS cmt 9- 5/8 in. bridge plug 13- 3/8 in. shoe 9-5/8qn. DY t ...~ Fluid x/o point ATTACHMENT Kemik Unit Well ..... in. liner top ~ 50 sks Class Ocmt 7 in. bridge plug ? in. shoe 150 sks Class O cmt 1 O0 3k3 C]833 O grot 100 sk3 Class O cmt 1234 ft RKB-MSL 14.4 ft RKEI-GL No. 1 72 ft 689 ft -- 1798 ft I800 ft 8-1/2in. TD AAAAAAA A AAAAAAA A ^ ^ A ^ A ^ , A A ^ ^ A ~ ~ , ^ ^ A A A ~. A , ~ ^ A ^ A ~ A , ^ A ^ ~' ^ ~ A / / / / ! /' ! / 76 ft -2587 ft (tagged) ~2670 ft 2787 ft 6745 ft · \/\ \ /\/ 7176ft 7339 ft (tagged) 7708 ft · 8578.ft (tagged) 8596 ft 8864- 8800 ft 8863 ft 9158 ft (tagged cmt top) 9429 ft · ::::::::::::::::::::::::: lllOlft 13501 ft '""'"'""'":"""' 16073 ft APl All depths DRT CMT No. 50-223-20006 Permit No. 7'0-60 5pud- 1/1/71 Suspended' 6/17/72 ' FEB ~4 ~95 03:23PH 9~756~S0~]-LRND.DEPARTM~NT 90? 852 Corporate Headquer[e~s, P.O. Box 129 ' 'Ba~:ow, Alaska · 99723-0129 · (~7} 65~-6 - jr (907) 852-6633 · FAX [907) 55~-5733 February 23, 1995 Peter T. Henley Permitting Superviaor Environmental Regulatory Affairs, Alaska BP Explore%ion P.O. BoK Anchorage, Alaska 99~19~6612 Kemik Unit #1 Well Plugging and. Abandonment , This letter will serve as the Arotic Slope Regional corporations' non-objec%i°n £or BP Exploration to leave the pilings in, place a= the Kemik Uni~ #1 well mite. , Very truly yours, ARCTIC SLOP~ REGIONAL CORPORATION william Thomas Director - Land ,Department · RECEIVED MAR' - 8 1995 ~.~sk~ Oil & Gas Cons. Commission Anchor~ An;:'.' ~;~. ....., -~- · '-.~:~ A'c',,- ~c.~. ~ve.' ,,~ · ,- ,,:~ .'J,) J :,~,c-c-n.;r.. · ~.~-~xn , ~,c.:.,.~ .... '--'3~ * .;,.;.'; !~.?..'..'.~..~ · -"'-., .:.;7. State of Alaska DEPARq34ENT OF ENVIRON~TAL CONSERVATION 411 W. 4TH AVENUE, SUITE 2C, ANCHORAGE,' ALASKA 99501-2393 David Johnston Alaska oil and Gas conservation Comm. 3001 Porcupine Or. /~,chorage, AK 99501-3192 PkOM, James R. Chatham Solid Waate Program Coordinator DATE: March 1, 1995 · . -'4339 subject: Kemik Unit gl ., , BP is ~akingplan~ to work on the well at the i'nactive, exDlora~ory drill site known as Kamik Unit ~1. The site has a numbe~ of pilings which were originally trimmed off below the ground surface., Frost Jacking has caused.the.pilings to sprout up.again. DEC does not believe it is necessary to take h~avy equipment to the ~ite and remove the'pilings. The site disturbanem would' probably be more disruptive ~han presence of the pilings. ~ on January 12 of this year' DEC £nformed BP that n~ fur=her clean-up activity is required at %be'site... D~C has noobjection to .leaving the pilings in place. , Tom Chapple, ADEC Regional Administrator Anchorage Glenn Miller, ADEC SW Pro,ram Manager Juneau RECEIVED MAR - 8 1995 A.~aska Oil & Gas Cons. Commission Anohor;' :~ STATE PII'ELINE COORDINATOR'S OFFICE Department of Environmental Conservation Department of Natural Resources Department of Fish and Game TONY KNO WLES, GOVERNOR Zli WEST 4Ih AVENUE. SUITE 2C ANCHORAGE, ALASKA 99501 PHONE: (907) 278-8594 {907) 278.8595 FAX: (907) 272-0690 .. January 12, 1995 Letter No: 94-08-DRT File No' 31~0. i5.202 CERTIFIED MAIL RETURN RECEIPT REQUESTED z o33 798 397 Mr. Steven D. Taylor BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 v- Dear Mr. Taylor: ENVIRONMENTAL .I ,N 1 3 1995 & REG. AFFAIRS Re: BP Exploration (Alaska) inc. Inactive Drilling Waste Disposal Facilib, Closures - Numerous.i~.~aa¢.t~i Sites The Alaska Department of Environmental Conservation (ADEC) has received and completed its review of },our August 9, 1993 letter, with enclosures, requesting approval for closure of BP Exploration (Alaska) Inc. Drilling Waste Disposal Facilities on the North Slope. These sites have been reviewed in accordance with the ADEC Interim Site Assessment Guidance for Inactiye Drilling Waste Sites, June 1991. This correspondence describes our review procedures, puts forward the department's findings, and takes action on the requests. Currently, the second draft of Alaska's new Solid Waste Regulation.s, 18.AAC 60, are under review, and this_second draft contains a chapter on Inactive Reserve Pit closures. The closure criteria in this proposed regulation parallels the closure criteria in the 199i Guidance Document. Closure under the 1991 Guidance Document should constitute closure under the proposed Solid Waste.Regulations if they are adopted as current drafted.. The Review Procedure The qualitative risk screening procedure required in the above referenced document determines whether a site presents negligible levels of risk, or if it is a significant risk generator. A decision scheme is then employed to establish (1) whether or not there is a RECEIVEb ~,t~ska 0il & Gas Cons. Commission Mr. Steven D. Taylor January 12, 1995 BPXA Inactive .Drilling Waste Disposal Facility Closure Approval basis of concern, and (2) whether or not a waste site is likely to present significant risk to .. human or environmental receptors. .. The first step in this screening criteria is establishing a basis of concern: "If the waste' site has rileased contaminants.or there are mechanism for potential releases and there-are receptors nearby, then, there may_be cause for concern, and'the waste sire-should be studied further," and "If ther~ is no release of contamination or no mechanisms for potential releases and there are no receptors riearby, then there is not a basis for concern and the waste site should be considered closed." The criteria that-are measured at a waste site to satisfy the above logical arguments are' Ex, idence of release of chemical contamination at the waste site in excess of Alaska - Water Quality Stand_ards for one or more target compounds, or - Mechanism for potent!al release, and Proximity of the waste site to biological receptors. If either of the first two criteria and the last criteria are met, there is a basis for concern, and before proceeding with Step 2, a corrective action plan shall be prepared for the site which shall identify alternative ways to correct or mitigate the basis of concern, prevent its recurrence, and select a preferred approach. Corrective action alternatives shall be described at a conceptual level, and the selection of a preferred approach shall be based on'balancing protectiveness with imple~entabi!ity and cost-effectiveness. ' The second step deten-nines whether contamination at a waste site present a risk to receptors that is significant. If risl~ is found not to be significant, it is considered to be"negl~g~bl~." '" The finding or significant risk is based on the likelihood of exposure and the likelihood of adverse consequences of exposure: "For risk to be considered significant, the receptors must be vulnerable to exposure, and the consequences of eXposure must be 'adverse' to human or animal health or the environment," and, conversely, "If exposure is unlikely or the consequences of exposure are not 'adverse,' then the risk is negligible. RECEIVED MAR -8 1995 ~.~ska Oil & (las Cons, Commission Anchor~ ? Mr. Steven D. Taylor January 12, 1995 BPXA Inactive Drilling Waste Disposal Facilit3, Closure Approval If risk at a waste site is signficiant, then corrective action should be taken. The criteria that are evaluated at a waste site to satisfy the logical arguments above are exposure criteria and consequence 'hriteria. .. . Exposure Criteria: . Receptor exposure is considered to be jike. ly when: -. - Contaminant release mechanisms are judged significant, or Containment migration is judged significant, or oo One or more contaminants are environmentally persistent. _If exposure is found to be unlikely, a finding of negligible risk is made' on the basis of absence of a likely exposure item and the action plan is evaluated under the Impact/Benefit Evaluation step. The purpose of this step is to determine whether the benefits of taking a corrective action would be greater than the impacts of taking such a corrective action. If an3' one of the exposure criteria are met, a finding is made that exposure is likely. Further screening then continues to evaluate Consequehce Criteria. Consequence Criteria: Adverse consequences of exposure to contaminants from reserve pits. are considered to be likely when: ' (a) The duration or frequency of exposure is sufficient to cause adverse health and environmental effects. This is evaluated by reviewing human and wildlife use patterns at a given waste site, waste site accessibility, and ground and surface water uses, and either; - - (b) The quantis, or concentration of one 6r more contaminants exceeds pertinent federal or state water quatit7 criteria or standards protecting health and/or the environment. M~asured contaminant concentrations in the' water will be compared with health and environ.mental standards and criteria for each target contaminant, to identify exceedanzes. When only human populations are at risk, health criteria are used. When only populations at risk are nonhuman (e o ~fish, wildlife vegetation) environmental criteria and standards are used, or; (c) One or more contaminants exhibit high acute toxicity. The NIOSH toxicity rating system (NIOSH 1974) will be used to identify contaminants highly toxic to mammals. This REEEIVED Mr. S~even D. Taylor Januau, 12, 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval information will be used to determine whether a target compound exhibits acute high toxicity. _ ._ If the duration and.frequency of exposure is insufficient to cause adverse effects, there is no need to evaluate the other two conse, quence criteria, and a finding of negligible risk is made. If the duration and frequency term is sufficient, but neithei- of the other two consequence criteria are met, a finding of negligible risk is made. The action plan is then evaluated under the Impact/Be.nefit Evaluation step. - If the duration and frequency of exposure is deterrnined to be sufficient to cause adverse effects and either of the other two consequence criteria are satisfied, then a finding is made that adve. rse consequences are likely, and the.risk at-a waste site is said to be significant. If the screening indicates that risk 'is significant, then the responsib!.e part), shall proceed with implementations of corrective actions. _ SITES CONSIDE~D FOR CLOSURE. - Based upon the above referenced criteria from the June 1991 LNTERI~{ SITE ASSESSM[ENT GUIDANCE FOR LNACTI~rE DRILLLNG WASTE SITES, the following sites listed below have been reviewed for closure' ARCTIC FOOTHILLS SITES Shale Wall Unit gl KemJk. Unit gl Kemik Unit #2 Kuparuk Unit 1 & lA Gubic Unit gl Itldllik Unit No. 1 Finn Creel: Unit 1 WEST SAK SITES West Sak 4 PUT RIVER SITES Put River 13-10-14, 14-10-14 Put River 24-10-t4 COLVILLE DELTA SITES Nechelik Unit SAG DELTA AREA Sag Delta Unit No. 1 Sag Delta Unit No. 2 10-11-16 Sag Delta Unit No. 11 OFFSHORE ISLANDS IN ALASKAN WATERS Alaska Island gl Challenge Island #'1 Niakuk 1, lA, 2, 2A Niak'uk 4. 5, 6 Long Island gl Niakuk 3 ~oh0rt Mr. Ste~,en D. Taylor Januar7 12, 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval The decision to grant closure approval on these sites has been based (1) on a review of the submitted inactive drilling waste site assessment documents listed below by the ADEC-PCRO Solid Waste, Water Quality, and Contaminated Site Staff, and (2) sim visits by PCRO staff during July of 1993 along with the resultant recommended remedial actions by ADEC undertaken at a certain number of these sites. Title: Inactive Reserve Pit Program, Assessment arid Closure -. . Supporting Documents: BPXA Video-documentation of Pit Closure/Site Restoration Comparative Analysis of Soil & Water .Samples Submitting Person: Covered Facilities: Dave Lowe, BP Exploration (Alaska) Above Named Facilities Synopsis of Closure Procedure: Closed as is. No further action is needed for the drilling waste facilities at these sites, except as noted below. CLOSURE A!~.. PROVALS The Department's decision upon the request for closure application submitted by BP. Exploration (Alaska) Inc. is to approve for the below listed drilling waste facilities sites, effective January 12, 1995. Upon review of the submitted sample results required under the 1991 Guid~ance, certain, remote sites exhibited metal concentrations and hydrocarbons in the reserve put surface waters and downgradient waters in excess of the Alaska Drinking Water Standards and Alaska Water Quality Criteria (AWQC). While there is a basis for concern for those sites-where exceedances occurred, there is also negible risk, and any corrective action warranted a.t these remote sites xffould .not be required-, realizing that the impact of the corrective action would be much greater than the benefits received. T.hese sites for the most part have revegetated, and any corrective action measures implemented would impact the established plant species at these sitez. These sites are Closed As Is. There are certain sites where corrective action is warranted, however, and Conditional Closure is granted, provided the corrective action stipulations described are completed to the department's satisfaction. REC£1V£D ~/XR-.8 1995 Oil & Gas Cons. Commission Anchor[ ~'' Mr. Steven D. Taylor January 12, 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval CLOSED AS I.S. Nechelik IJnit gl Sag Delta 11 . .. Alaska-Island #1 Niakuk 4, 5, 6 Challenge Island #1" Long Island #1 Niakuk 1, IA, 2, 2A Niakuk 3 Sag Delta 8 Sag Delta 3 & 4 Sag Delta 5 West Sak 4 Put River 13-10-14, 14-10-14 Put River 24-10-14 Kemik Unit #2 Gubic Unit #1 cONrDITiONALLy cLOSED These closure conditions were placed onthe below-named sires f°Ilo~!ing, the site visit/closUre package evaluation. These conditions have been met at each sire and are now Considered CLOSED. Shake Wail Unit #1 Remove unused drilling additives and pallets. Kernik Unit #i Stabilize any exposed drilling waste in reserve pit Fertilize, plus seed and/or transplant with con~nercial Or indigenous plant material . · Kuparuk Unit 1 & lA Smbilize any exposed drilling waste in reserve pit Surface preparation of site needed (scarify, add soil amendments, fertilize) Monitor site using aerial photography kqAR -8 1995 oil & fas oons. Oommio$ion Anchor~ ~' Mr. Steven D. Taylor January 12, 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval Itkillik Unit No. 1 Stabilize an), exposed drilling waste 'in reserve pit These conditions have been placed on the below-named sites following the site visit/closure package evaluation. Once these conditions have been met, these sites will be considered CLOSED' ..Finn Creek 1 Remove stockpiled debris from pad Fertilize, plus seed and/or transplant with commercial or indigenous plant material to enhance natural biodegradation of residual hydrocarbon contamination, in the soils and waters at the site _ Stabilize any exposed drilling waste in the reserve pit .:~ Sag Delta Unit No. 1 Sag Delta Unit No. 2 10-11-16 Cap existing reserve pits with available gravel and recontour pits to blend into surrounding terrain Terms and Conditions These closure approvals are subject to the following terms and conditions' FULL SITE CLOSURE: The approval granted by this letter is for the inactive drilling waste sites only, as required under 18 AAC 60.500 (d). Closure for the pad as a whole must be coordinated between the owner/operator and the appropriate state (ADNR, ADF&G, AoGcc), or federal (BLM) agency. Additionally, should any contamination from historic spills be found on the pad outside the drilling waste site (reserve pit area), notification needs to be made to the ADEC/PCRO Contaminated Sites Section (271-4399). RF. CF.I¥£D k~/XR - 8 1995 Anchorz Mr. Steven D. Taylor January 12, 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval N'EW INFORMATION: Should additional information cOncerning environmental conditions at the facility make - further actions necessary to protect human health or the environment, the Department reserves the right to require additional investigation, assessment, monitoring, or remediation at the facility. - Mr: Steven D. Taylor .. Januai'y 11, 1995 BPXA Inactive Drilling' Waste Disposal Facility Closure Approval DUTY TO RESPOND: Notwithstanding any other provisions or requirements 6f this closure approval, a person causing or permitting the discharge of oil or other hazardous substances is required by law to immediately contain and clean-up the discharge. (AS 46.04.020; 46.09.020). .. COMPLIANCE ~YITH APPLICABLE LAWS: If amendments to this closure approval are necessary to meet the requirements of an), new laws or regulations, the facilitT owner/operator must submit an application for amendment to the Department at the above address. The facility owner/operator must adhere to all applicable state statutes and reg-ulations as they may be amended, from time to time. If you have an5, 'questions, please do not hesitate to contact Tim Law at 271-4051 of this office. Sincerely, ' ADEC Regional Administrator Pipeline Corridor Region RECEIVED Gas Cons. Commission Anchor~ CC: John Santora, BLM/JPO Dave Lowe, BPX Anchorage .. AOGA/Anchorage Jel-ry Brossia, ADNR/SPCO Nancy Welch, ADNR/Fairbanks A10tt, ADFG/F'fiirbanks Glenn Miller, Doug Bauer, ADEC/Juneau Jim Haynes, ADNR/Anshorage Keith Mueller, USFWS/Anchorage Jessie Kaleak Sr., Mayor NSB/Barrow Para Miller, The Wilderness Societ-y/Anchorage Larry Landry, Northern Alaska Environmental Center/Fairbanks RECEIVED ~AR -8 199.5 0ii & Gas Cons. Commission Anchor~,.~, TO: THRU: FROM: RES ENG SR ENG State of G "L~q~AS ST .i ENG ASST. SR GEOI.~ GEOL A~S'9' GEOL ASST STAT TECH'~i SU~~£~CT: Kemik Unit #1 DEPARTMENT OF ENVIRONMENTAL CONSERVATION 411 W. 4TH AVENUE, SUITE 2C, ANCHORAGE, ALASKA 99501-2393 David Johnston Alaska Oil and Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, ~ 99501-3192 James R. Chatham% ~ Solid Waste Program' Coordinator BP is making plans to work on the well at the inactive exploratory drill site known as Kemik Unit #1. The site has a number of pilings which were originally trimmed off below the ground surface. Frost jacking has caused the pilings to sprout up again. DEC does not believe it is necessary to take heavy equipment to the site and remove the pilings. The site disturbance would probably be more disruptive than presence of the Pilings. On January 12 of this year DEC informed BP that no further clean-up activity is required at the site. DEC has no objection to leaving the pilings in place. cc: Tom Chapple, ADEC Regional Administrator Anchorage Glenn Miller, ADEC SW Program Manager Juneau ~as~ Oil .& Gas Cong. Commission ~chora~e BP EXPLORATION February 23, 1995 Mr. Bill Thomas, Land Manager Arctic Slope Regional Corporation Planning Department P.O. Box 129 Barrow, Alaska 99723 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 COMM - _ .% ~ SR ENG ENG ASS-~ ~ ENG ASSr' ~R GEOL~ GEOL ~EOL ASST~~ ~ TEC~'~ STAT TEC~ ADDITIONAL INFORMATION REGARDING PLANNED KEMIK UNIT #1 WELL,PLUGGING AND ABANDONMENT Dear Mr. Thomas' Thank you for your January 31, 1995 letter of non-objection regarding our planned Kemik Unit #1 well plugging and abandonment. The purpose of this letter is to request your concurrence with our plans to leave old pilings in place, as outlined below. Since our January 25, 1995 request to you, there has been some discussion with the Alaska Oil and Gas Conservation Commission (AC)GCC) regarding old pilings that remain at this site. BPXA has recommended to AC)GCC that these pilings be left in place. This recommendation is based on previous unsuccessful experience with trying to remove the pilings: after excavating to a 2-foot depth around the pilings and blasting with dynamite, frost heaving forces had re-exposed from 6 to 12 inches of pilings above the ground surface within 2 years. AOGCC has agreed to allow BPXA to leave the pilings in place provided we receive the concurrence of the Arctic Slope Regional Corporation and the Alaska Department of Environmental Conservation. If you concur, we would appreciate a response as soon as practical, since activity is scheduled to begin in early March. If you have any questions please call Karen Wuestenfeld at 564-5490. · Environmenta~ffairs, Alaska RECEIVED FEB 2 4 1995 Aiaska Uii & Gas Cons. Coatatissbrt Anchorage Mr. Bill Thomas~ \ February 25, 1995 Page 2 Dave Johnson, Alaska Oil and Gas Conservation Commission Keith Quintavell, North Slope Borough Leon Lynch, Alaska Department of Natural Resources RECEIVED FEB 2 4 1995 Ataska Oil & Gas Cons. Commission Anchorage FACSIMILE COVER SHEET E. A. Opstad & Associates P. O. Box 190754 Anchorage, Alaska i)9519-0754 Geosclence · Engineering · Project Management Tel/FAX: (907)345-6346 I I IIIII IIII II II I To: Russell Douglass From: Erik A. Opstad Company: AOGCC Date: 02/08/95 Telephone: 279-1433 Pages: 4 FAX No: 276-7542 Time: 3:45 PM Subject: KEMIK UNIT NO. 1 ABANDONMENT ......... 00000000000000- , ~uss: BP Exploration has asked me to develop a work plan to bring the Kemik Unit No. I well into compliance with the state's abandonment regulations as .principally cited under 20 AAC 25.105 and 20 AAC 25.107, To reduce the cost and environmental impact of this work I would like the Commission to consider allowing me a variance on one element in the regulations, The background for this request is as follows, OVERVIEW The Kemik Unit is located approximately 30 miles east of the Trans-Alaska Pipeline System's (TAPS) Pump Station No. 2. The Unit's No. 1 well was spudded January 1, 1971 by Forest Oil Corporation and drilled to TD at 16, 073 feet to evaluate an anticllnorium comprising numerous thrust sheets, During the second season of operation, gas was discovered in a shallow portion of the hole. Referencing a RKB of 14.4', the hole was plugged back to 9158' MD and perforated between 8664'. 8780' MD, Drillstem testing produced 0.0 gravity gas at 10 MMCFPD from the Shublik Formation from an original reservoir pressure of 2678 psia. Following the ddllstem test the well was suspended on June 17, 1972 by setting a sedes of 3 cement plugs plus 3 bridge plugs, with the shallowest cement plug set in the 9-5/8" casing at approximately 2335' MD. After backing off the 9-5/8" casing string at 1,798' MD, water based mud was left in tl~e well to 55' and the well capped with 13-3t8" casing riser. Reports from recent site visits indicate that the well has since filled to surface with water. The runoff waters were frozen to surface as a January 1995 site Inspection and due to area permafrost are expected to stay frozen, save the top few feet during the summer [Attachment 1]. RECEIVED Fp~m ' E.A. OPSTAD qNCHORRGE~qSKR · PHONE No. : gO? 345 6346 (i' Feb. 08 1995 4:54PM P02 Although the well has been thoroughly plugged at depth, to meet the abandonment requirements stipulated by 20 AAC 25.105, the following remaining tasks must be completed: "by displacement method, a cement plug at least 150 feet in length with the top of the plug 5 feet or less below rig grade elevation upland .... must be spaced within the smallest casing extending to surface" [20 AAC 25.105(i~)] . "Cements used for plugging within zones of permafrost must be designed to set before freezing and I~ave a Iow heat of hydration." [20 AAC 25. lO5(j)] . Remove all wellhead equipment and cut casing off 3 feet below the surface. Weld on subsurface identification plate. Remove cellar timber and back-rill to grade. Pick-up any remaining.debris. [20 AAC 25.170(a)] VARIANCE What i would like the commission to consider is granting an variance to 20 AAC 25.105(i0 (the requirement for a 150' surface cement plug:}, as can be granted under 20 AAC 25. I05(m), As an alternative, I would simply like to place a 5 to 8 foot cement plug below wellhead out-off in the 13-3/8" casing, then normally complete the other 'required abandonment tasks. Spedfically then I would like a variance from the 150' surface plug requirement to a 10' below grade requirement, The logic behind this request is as follows. The only perforated interval in the well is thoroughly isolated at depth by 3 cement plugs and 3 bridge plugs. , The upper portion of the well Is thoroughly plugged by perpetually frozen drilling mud down to the base permafrost at ±, 1,800 feet, , Drilling the top off of a perfectly good plug of frozen drilling mud simply to replace it with a cement plug offers no practical increase in well security or fresh water protection that I can see. , Installing a 150' cement plug can only be accomplished by mobilizing a consiclerable amount of heavy equipment, at significant cost, ancl with a real potential for damage to the delicate tundra environment. . Our proposal to place a short cement plug at the top of the welt will displace the near surface mud column that might melt in the summer, thereby maintaining a solid plug year round. This work and the other associated regulatory abandonment work can be accomplished with minimal equipment, personnel and environmental impact, while at the same time meeting the intent and technical requirements of [20 AAC 25.105(j)]. RECEIVED FEB 09 }995 Alaska 0il & ~3~ Cons, rmm : E.A. OPSTAD ANCHORAGE ~KA PHONE No. : gO? 345 G34G Feb. 08 1995 4:55PM This Fax is not intended to be a formal request for a variance, but I woul(l like to know Informally if the Commission would give such a request consideration if formally presented. There'is · feidy short time fuse on the matter, so rll call you tomorrow to chat, Thanks for your help. Best regards, Erik ,R E'CE IVED Anchorage PHONE No. ' 98? 345 6346 ATTACHMENT Kemik. UniL Well No. ~eb. 08 199S 4:55PM P04 ppg mud 50 in. sho~ 20 in. shoo o. 9- 5/8 in. "disconnect" point I I,3 ppg mud ~'tuid x/o point 9,8 ppg mud 100 sks Clo~s O crn[' [1 t.1 ppg mud g-$/B in. bridge plug 1 $- 5/8 in. shoe 9- S/8dn. DY Fluid x/o point i O0 sks Cl~ssO cmt '72 ft 68.-9 ft 1798 ft 1803 ft 2576 ft 2587 ft (t~gged) 2670 ft 2787 ft 6745 ft All deptlis DRT CMT ? in. liner top · 7176 ft 7.339 ft (tagged) 10';7' ppg mud. 1 2:3;4 ft RKB-M,SL 1 4.41 ft RKD-GL 9-5/8 in. shoe 50 sks Closs Ocrnt '7 in. bridge plug 7 in. bridge plug Perforations 7 in. PBTD ? in. shoe 1 50 3ks Class G cmt I O0 sks Closs O crnt 100 sk3 Closs O cmt 8- 1/2 in. TD 770,'3 ft REC"EIVED 85'78 fi .(tegged) FEB 09 t,995 8596 f~ Alaska Oil & Gas Cons. Comm~sStOr' Anchorage 8864-8000 ft 886,3 ft 9158 ft (toggod crnt top) ~7429 ft Il I01 ft 13501 ft 16075 ft APl NO. 50-223-20006 Permit No. 70-60 Spud: 1/1/71 Susponded: b/17/72 BP EXPLORATION ARCO Alaska, Inc. To: From: David W. Johnston Chairman Alaska Oil & Gas Commission Steve Horton, Drlg Mgr Shared Services Drilling Date: 0913' 'ST^' ST,~ ._.- :ILE Subject: Suspended wells Compliance with regulations In response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Horton Drilling Manager CCi Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan RECEIVED OCT 1 4 1994 Alaska 0il & Gas Cons. Commission Anchor~ Suspended Well~, Request to retain suspension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-/¢'04 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13)in this area. MPB-02; 029-20662-00 81-/¢(142 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-,¢001 Future utility as a Schrader Bluff producer with producing utility when surface infrastructure is installed on A pad. MPN-01B; 029-21053-02 84-OO 13 N-01 B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-O 110 C-16 has recompletion potential in the Kuparuk "C" sand and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The wellbore is strategically located on a gravel island and may possess utility in either production or injection operations. DNR recently certified this well as capable of production. No Point #1;029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-0200 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-20176-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production' test. Sag Delta #5, 029-20527-00 80-0129 Area being drained by L5-26 (high gas well), L5-28, and L5-36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 well. Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80-0121 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32A, 029-21924-01 93-0113 Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10A, 029-20765-01 91-0123 S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-0115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. PR 33-12-13, 029-20047-00 69-01 04 The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island #1,289-20018-00 81-0119 Alaska Island #1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1 ). Niakuk #lA, 029-20156-01 76-0028 Niakuk #lA was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). Niakuk #2A, 029-20180-01 76-0079 Niakuk #2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01, 029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit #1,223-20006-00 70-0060 Kemik Unit #1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress. Site inspection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-0140 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-0080 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-0066 MP 33-11-12, 029-20504-00 80-0O92 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11-12, 029-20356-00 78-0102 MP 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIC, KEL, GOVERNOR -. 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907} 279-14.33 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc ? O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as~r~qu-i~20 AAC 25.110(e), must have well site ~_~is[ y~r~i~~snow covering the locations. Cha±rman ' Attachments c: Blair Wondzell bew/llbpsusp 8/15/94 BP SUSPENDED WELLS SINCE 1980 PAGE AUGUST 1994 PERMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BAY UNIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 i DEV SUSP PRI3DHOE BAY U~IT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BAY UI~IT 31-11-13 DEV SUSP P~U ~P 32-30-11-13 I DEV SUSP P~U MP22-31-11-13 2 DEV SUSP ALASKA ISLAND 1 EXP SUSP ~ILNE POINT UNIT B-02 DEV SUSP ~ILNE POINT UNIT A-03 DEV SUSP MILNE POINT UNIT N-01~ DEV SUSP NIA~UK 4 EXP SUSP NtAK~3K 5 EXP SUSP MILNE POINT LrNIT C-16 DEV SUSP PRUD~OE ~AY UNIT Y-22A DEV SUSP PT MCINTYRE' P2-59 EXP SUSP PRUD~OE ~A~ UNIT S-10A DEV SUSP NORT~WEST ~ILNE 1 EXP SUSP PRUD~OE ~AX UNIT U-01 D~V SUSP PRUD~OE BAY U~IT Z-32A DEV SUSP NO POINT I DEV SUSP STATUS DATE 4/15/80 10/11/80 4/29/81 12/24/80 4/15/81 4/13/81 2/20/81 1/18/81 2/14/81 6/08/82 5/27/82 12/lO/83 4/27/84 2/17/85 4/18/85 lO/27/93 lO/29/88 12/22/9o 11/o6/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 O7 27 36 05 30 30 11 19 23 30 25 25 10 33 14 35 25 18 19 O6 13N llN 11N 11N 12N 12N 10N 11N llN 10N 13N 13N 13N 12N 12N 13N 11N 12N 12N 14N 11N 11N 13N 010E 012E 012E 012E 016E 015E 013E 013E 013E 022E 011E 010E 010E 015E 015E 010E 013E 014E 012E 009E 013E 012E 010E MER U U U U U U U U U U U U U U U U U U U U U U U 8/15/94 BP SUSPENDED WELLS PRIOR TO 1980 PAGE 1 AUGUST 1994 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY UI~IT 33-12-13 DEV SUSP KEMIK UNIT I DEV SUSP PRUDHOE BAY I/NIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-A EXP SUSP NIAKUK 2-A EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDHOE BAY I/NIT TERM C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 04 26 26 35 35 10 03 11N 12N 01N 11N llN 12N 12N 12N 12N 11N 11N RNG 016E 013E 020E 013E 016E 015E 015~ 016E 016E 016E 012E MER U U U U U U U U U U U STATE OF ALASKA ALk.,XA AND GAS CONSERVATION C r~lS" N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of ODe[a.tor. ~canoara Azas~a Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2396' NEL, 2073' NSL, Sec. 17, T1N, R20E, UN At top of productive interval At effective d~etlh1 Vertical At total depth 3LDatum elevation fDF or KB) 234' RKB - MSL 6. Unit or Property name Kemik Unit 7. Well number Kemik Unit Well No. 1 8. Permit number 70-60 9. APl number 50...223-20006 10. Pool Wildcat feet 11. Present well condition summary Total depth: measured true vertical 16073' feet Plugs(measured) 16073' feet See Attachment Effective depth: measured true vertical 8853' feet Junk (measured) 8853 ' feet None Casing Length Structural Size Cemented Measured depth 30" 154 sks Fondu 72' Conductor 20" Surface 13-3/8" Intermediate 9-5/8" Production 7" Liner 1470 sks Fondu 689' 4270 sks Fondu 2670' 1160 sks Class G + 7708' 150 sks Class G (2nd Stage) 550 sks 9158' Perforation depth: measured 8654'-8800' 4 spf (1/2" size) true vertical ~ueVerticaldepth 72' 689' 2670' 7708' 9158' ~bing (size, grade and measured depth) None Packers and SSSV(type and measured depth) None Reason for Extension: This suspended well is being considered for possible recompletion with the potential for future use as a Kemik Unit development well. ,;'% 12.Attachments Description summary of pr~o~osal [] Detailed operations Request extension under 20 AAC 25.1.~3'~'~, '~.. 2, 3. ~' 13. Estimated date for commencing operation ~tch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~. ~, ~ TitleDivision Drillincj Engineer Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance Approved by Form 10-403 Rev 12-1-85 Commissioner the commission Date Submit i/n triplicate Standard Alaska Production Ceml~~ ' 900 East Benson B~ Jrd P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 17, 1986 STANDARD ALASKA PRODUCTION Mr. Lonnie C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kemik Uojt Well No, 1 Dear Mr. Smith, Enclosed please find a Well Completion Report, Sundry Notice w/plug summary and a wellbore diagram for the above referenced well. The documentation is submitted pursuant to the October 2, 1986 letter to you from Stu Hirsh, Senior Landman, Standard Alaska Production Company. As operator of the Kemik Unit for BP Alaska Exploration Inc., Standard Alaska Production Company will submit Sundry Notices for the Kemik Unit No. 1 well on an annual basis with other wells currently carried by SAPC on suspended status. Should you have any questions concerning this well, please contact me at" 564-5007. Attachments R. S. Allan Division Drilling Engineer R. H. Reiley J.F. Gulick M. Williams S. Hirsh - two copies Well file A unit of the original Standard Oil Company Founded in Cleveland. OhJOr in 1870. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ]~] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 70-60 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 223-20006 4. Location of well at surface 9. Unit or Lease Name 2396' WEL, 2073' NSL, Sec. 17, T1N, R20E, UM Kemik Unit At Top Producing Interval 10. Well Number Vertical Well Kemi,k-unit Well No. 1 At Total Depth 11. Field and Pool Vertical Well 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Wildcat 1234 ft. RKB - MSLI Fairbanks 021270 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 1 Jan 197,1 19 May 1972 17 June 1972 --- feet MSLI None 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19, Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 16073' MD + TVD 8863' (MD+TVD). YES[] NO~-qI None feetMD --- 22. Type Electric or Other Logs Run Schlumberger: DIL, DENSITY-GR, SONIC-GR, CBL, DIPMETER SURVEY 23. CASING, LINER AND CEMENTING RECORD KBE = 14.4' Above ground level SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157 5'BL Surface 72' 36" 154 sks Fondu [782' of 9-5/8" 20" 133 K55 Surface 689' 26" 1470 sks Fondu ~79/ft.. casing 13-3/8" 61/68 K55 Surface 2670' 17-1/2" 4270 sks Fondu / 9-5/8" '47' S95/N80 Surface 7708' 12-1/4" 1160 sks ClassG+150s~sClassG (2stage 7" 29 N80 7341' 9158' 8-1/2" 550 sks Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None Interval: 8664 ' -8800 ' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 4 spf (1/2" size) DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED None -- 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 25 May 1972 " Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO llJunel,9.72 24-1/2 TEST PERIOD ~ 0 7,500+/- 0 7/8"I --- Flow Tubing Casing Pressure CALCULATED.~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) · 280- 0 24-HOUR RATE "F 0 5-10,000 0 None Press. 2500 }si 28. 'CORE DATA i EC F. iV _ _ Brief description of Iithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core No. 1 - 8622'-8678', Cut 56', RecoVered 56' 8622'-8638', Shale, 8638'-8643' Shale & Limestone 8643'-8678' Fractured Limestone .- No shows Core No. 2 - 10994'-11044' Cut 50' , Recovered 50' , Limestone w/no shows Ancho;'a~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ ./ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Okpikruak Ground level Shublik Formation Kingak Shale 2000' Measured DST No. 1 - Open hole test. Packer failed. Kemik Ss 2420' Depth & No. Test Kingak Shale 2510' True Vertical DST No. lA -Open hole test. Packer failed. No. Test Kemik Ss 3587' approximately DST No. 2 - Open hole straddle test of Kingak Shale 3850' same - interval 8679'-8719' ~ Kemik Ss 4433' Depths are IHP: 5060; IFP 14 minutes, 1536 Kingak Shale 4730' RKB .v ISIP 60 minutes, 4496; FFP 360 minutes 20'22 Sag River Ss 8518' FSIP 60 minutes, 4496; FHP 4872 Shublik Li 8538' Sadlerochit 8830' Estimate 12 NLH CFD from Choke Data (dry gas) Lisburne Li 10950' Recovered 210' slightly Kayak 15968' gas cut mud (pressures are psig) 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Division Drilling %F~ ~ ~'~ ~ Date Signed ' Title Engineer I\ \ 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 toot. 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 STATE OF ALASKA ALAS . OIL AND GAS CONSERVATION COM ._,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. r~~eA~t~ka Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2396' NEL, 2073' NSL, Sec, At top of productive interval A~ effective d,e, p t,h, erti cal Hem m At total depth 17, T1N, R2OE, UM 6. Unit or Property name Kemi k Unit 7. Well number Kemik Unit Wel 1 No. 1 8. Permit number 70-60 9. APl number 5o-223-20006 10. Pool Wi'ldcat 11. Present well condition summary Total depth: measured 16073 ' true vertical 16073' feet Plugs (measured) feet See Attachment Effective depth: measured 8863' true vertical 8863' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Length Size 30" 20" 13-3/8" 9-5/8" 11 Cemented Measured depth 154 sks Fondu 72' ]470 sks Fondu 689' 4270 sks Fondu 2670' 1160 sks Class G + 7708' 150 sks Class G (2nd Stage) 550 sks 9158' Perforation depth: measured 8664'-8800' 4 spf (1/2" size) true vertical True Vertical depth 72' 689' 2670' 7708' 9158' Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None Reason for Extension' This suspended well is being considered for possible recompletion with the potential for future use as a Kemik Unit development uel 1. 12.Attachments Description summary of proposal [] Detailed operations ~ocra.~mF~l CKdketch E3 Request extension under 20 AAC 25.170(b) l, 2, 3, 4 ........ 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Alaska Oil & Gas Cons, Commission Date !5. J, hereby certify that the foregoing is true and correct to the best of my knowledge ~ed ¢. ~. ~ TitleDivision Drillinq En,qineer Commission Use Only Date ItllEl~ Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel by order of Commissioner the commission Date // Form 10-403 Rev 124-85 Submit in triplicate EEMIE UNIT NO.I PLUOS (measured.brt) APl # ~0-223-20006 8-1/2 in. hole (TI~. 16073 ft) 100 sks Class G plug: bottom e 13501 ft 100 sks Class G plug: bottom e 11101 ft 150 sks Class G plug: bottom ~ 9429 ft, top ~ 9158 ft (tagged) 7 in. liner PBTD e 8863 ft (shoe ~ 9158 ft) Bridge plug e 8596 ft Bridge plug ~ 8:578 ft (tagged). 50 sks Class G plug on top of bridge plug. 9- 5 / 8 in. casinn -- 100 sks Class G plug: bottom ~ 7176 ft Bridge plug ~ 2587 ft (tagged) 100 sks Class G plug: bottom ~ 2~76 ft Casing "disconnected" and recovered e 1798 ft Wellhead Details: 20-3/4 in. 2000 psi WP starting head installed on 20 in. casing. 13-3/8 in. casing landed in starting head. 20-3/4 in. 2000 psi x 12 in. 3000 psi WP casing spool installed on 20-3/4 in. starting head. Suspension: I/2 in. plate bolted to top of 12 in. 3000 psi x 20-3/4 in. 2000 psi casing spool with 6 in. hole in center. 13-3/8 in. OD x 6 ft long casing stub welded to 1/2 in. plate with 1/4 in. solid plate welded to top of stub. RECEIVED Oil a. Gas Cons, Comrnissior~ Anchorage Kemik Unit Well 1.2 ppg mud 30 i n. shoe 20 in. shoe 9- 5/8 in. "disconnect" point F1 uid x/o poi nt F~ 11.3 ppg mud ~ 9.8 ppg mud 1 O0 sks Class G cmt 9-5/8 in. bridge plug 1 3- 3/8 in. shoe 9- 5/8 in. DY Fluid x/o point ~ I 1.1 ppg mud 1 O0 sks Class G cmt 7 in. liner top JAAAAAAAAAAAAAA ~AAAAAAAAAAAAAA ~AAAAAAAAAAAAAA 72ft 689ft 1798 ft 1800 ft All depths §RT 2576 ft 2587 ft (tagged) 2670ft 2787ft CMT 6745 ft 7176 ft 7339 ft (tagged) 9-5/8 in. shoe 7708 ft ~ 10.7 ppg mud 1234 ft RKB-MSL 14.4 ft RKB-GL 50 sks Class G cmt 7 i n. bridge plug 7 i n. bridge plug Perforations 7 in. PBTD 7 in. shoe 150 sks Class G cmt 1 O0 sks Class G cmt 1 O0 sks Class G cmt 8-1/2in. TD 8578 ff (tagged) RECEIVED 8596 ft 8864-8800ft 8863 ft Alaska Oit & Gas Cons, Co~,.,n~>sLm 9158 ft (tagged cmt top) 9429 ft 11101 ft 13501 ft 16073 ft APl No. 50-223-20006 Permit No. 70-60 Spud- I/I/71 Suspended: 6/17/72 Standard Alaska Production Company f 900 East Benson Boulevar P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-51 ! ! October 23, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: AK7-0016-UA-01 Kemik Unit Agreement Designation of Operator Dear Mr. Chatterton, I have been working with Commissioner Lonnie C. Smith in an effort to bring your Kemik Unit files up to date. In this regard, attached you will find two original Designation of Operator Forms executed by Standard Alaska Production Company as operator and BP Alaska Exploration Inc. as owner of the Kemik Unit. Standard Alaska Production Company assumed operating responsibility for the Kemik Unit effective January 1, 1978 by virtue of a Contractor Operating Agreement with BP Alaska Exploration Inc. Our Drilling Department will complete and file a Sundry Notice for the suspended Kemik Unit well No. 1 on an annual basis. Please direct any technical questions regarding this well to Mr. Richard Reiley, our Manager of Drilling. Should you have any questions or need any additional information, please advise. Sincerely, Stu Hirsh Senior Landman cc: R. A. Straub - External Affairs J. H. Dickey - SAPC Legal D. J. Moon - Houston FID J. Miller - BPAE Inc., Anchorage S. DiDomenico - BPAE Inc., San Francisco i. ';T 2 ? 1986 Alaska. 011 & (h~ Cor~s. C:~;?.,mtssior, SH: it: 5761W A unit of the original Standard Oil Company Founded in Cleveland, Ohio. in 1870· STATE OF ALASKA f" ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner BP Alaska Exploration Inc. 2. Address 100 Pine Street San Francisco, CA 94111 3. Notice is hereby given of a designation of operatorship forthe oil and gas property described below: Property designation: Kemik Unit Legal description of property: TiN, R20E, U.M. Sec. 16: All Sec. 17: All Sec. 19: All Sec. 20: All Sec. 21: All Sec. 22: All Containing 3,840.00 acres more or less Property Plat Attached [] 4. Name of Designated Operator Standard Alaska Production Company Address P.O. Box 196612 Anchorage, Alaska 99519-6612 !986 5. Effective date designation January 1, 1978 6. Acceptance of operatorship forthe above described property with allattendantresponsibilities and obliga- tions is hereby acknowledged by Standard Alaska Production Company ....Sign Title vice President - Operations 7. Thc=Y-o~ner/bXe~eby certifies that the foregd{ng is true and correct Date 10/3/86 Signed ~,, Form 10-411, 12-1-85 Standard Alaska Production Company 900 East Benson Boulevc, P.O. Box 196612 Anchorage, Alaska 995 ! 9-6612 (907) 564-$! 1 i October 2, 1986 Mr. Lonnie C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Standard Alaska Production Company Lease 507-180 (F 021270) Kemik Unit Well No. 1 Dear Mr. Smith, Your letter of January 7, 1985 concerning the Kemik Unit has been forwarded to me for reply. Standard Alaska Production Company (SAPC) operates the Kemik Unit for BP Alaska Exploration Inc. by virtue of an operating agreement effective January 1, 1978. A designation of operator form will be forwarded to you with in the next 30 days. As unit operator, SAPC is responsible for all lease rental/minimum royalty payments and for making all necessary filings with the AOGCC. Therefore, all correspondence pertaining to the Kemik Unit should be sent to the SAPC Land Department at our letterhead address. You are correct regarding the status of lease F-021270. Kemik Unit leases F-021270 and F-021271 were conveyed to the Arctic Slope Regional Corporation effective June 3, 1977. Our drilling department routinely, and on an annual basis in August of each year, files Sundry Notices for our suspended exploratory wells with the AOGCC. You can therefore, expect to receive Sundry Notices for the Kemik Unit Well No. 1 in the future. I have been advised that a notice for the Kemik Unit Well No.. 1 will be included with this years filing. You will also receive a completion report indicating that the Kemik Unit Well No. 1 has been completed as a suspended well. I trust I have adequately addressed your concerns. Should you have additional questions or need additional assistance in this matter, please contact me at 564-4841. Sincerely, .::.. Stu Hirsh Senior Landman cc: Bob Allan - Drilling R. A. Straub, External Affairs, SAPC, Anchorage J. D. Moon - Houston FID J. Miller - BPAE, Inc, Anchorage S. DiDomenico -BPAE, Inc., San Francisco SHH:lmt:5743W RECEIVED OCT o 7 1986 Alaska Oil & 6as Cons. Commissicn Anchorage A unit of the original Standard Oil Company Founded in Cleveland. Oh;o, in }870. Telecopy No. (907) 276-7542 September 3, 1986 Mr. Dudley S. Basham 6009 Hudson Street Dallas, TX 75206 Re: Forest Oil Corporation Kemik No. 1 API No. 50-223-20006 Dear Mr. Basham: This is in response to your letter received September 2, 1986 requesting A.O.F. data on the subject well. Ail of .the test data reported by the operator of the well is reflected on the following documents, copies of which are enclosed: - Well Completion RePort - Test Data Sheet - Summary of Operations, pp. 5 & 6 Please submit remittance in the amount of $1.25 to cover duplication costs. Glad to help. William Van Alen Sr. Petroleum Geologist Enclosures jo/B..WVA.18 RECEIVED Alaska Oil & Gas Cons. CornmJssio~ Anchorage January 7, 1985 Mr. John Miller British Petroleum Alaska Exploration, Inc. 550 W. 7th, Suite 1840 Anchorage, Alaska 9950'1 RE: Kemik Unit Well No, 1 Dear Mr. Miller: We understand that ~British Petroleum Alaska Exploration, Inc. is the current lessee and operator of lease Fairbanks 021270. The Kemik Unit Well No. 1 was drilled on this lease by Forest Oil Corporation in 1972. After flow testing over 7,000 MCFGPD, the wellbore was plugged on June 17, 1972. A "Well Completion or Recompletion Report and Log" was submitted by Forest Oil Co~oration in August 1972, wherein the well was classified as a gas well. We have been informed that the mineral interests~ covered by lease Fairbanks 021270 were transferred to the Arctic Slope Regional CorPoration sometime in 1978. Since the wellbore is plugged and the well is not capable of. production, we are requesting you to submit a revised "Well Completion or Recompletion Report and Log, Form 10-407, which classifies the well as either suspended or abandoned. The form "Sundry Notices and Reports on Wells", Form 10-403, must be submitted'to request annual extensions of the suspended status. FOrmal abandonment of the Well will require a final abandonment inspection. dlf:A.HJH. 21 November 8, 1984 Mr. Thomas N. Smith Division of Geological and Geophysical Surveys Pouch 7-028 Anchorage, Alaska 99510 Re: Preparation of Petrographic Thin-Sections on Ditch Cuttings and Core Chips From State Sample Library. Dear Tom: Pursuant to the November 8, 1984 discussion with you, permission is hereby granted to Division of Geological and Geophysical ~ Surveys· (DGGS) tm extract a maximum 1 cc. of core material ~er foot of core from the state'~s set of samples and core chips for the sole purpose of preparing the petrographic thin-sections within the designated intervals, in the following wells, subject to the conditions listed below: ' I. Sample Set No. Wel~ Interval amp 1 e_s II. 303 McCulloch Fin Creek 10420 - 10520 3 Unit #1 299 Forrest Kemik U. ~1 4430 - 4660 3 274 Home Bush Fed. ~1 11240 - 11300 2 263 Atl. Richfield Nora 12490 - 12550 3 Fed #1 138 Atl. Richfield Susie 13020 - 13060 1 Unit #1 504 Sohio Sag Delta ~8 9910 - 10130 4 336 B.P. Niakuk ~1 9620 - 9980 4 b~ATERIALS TO BE SUBMITTED Petrographic Thin-Sections from Ditch Cuttings and Core Chips. III. CONDITIONS Cuts of the'sample and/or core material on the subject wells in the State collection are to be extracted only from those individual envelopes or bags in which total content of core material is greater than 10 cc. (No cuts are to be extracted if the volume of material in the individual envelope is less than 10 cc.) 2~ DGGS will provide the State with a list of the specific core footages from which material was extracted. 3~ The above-indicated materials are to be prepared covering the specified intervals in these wells, ~ All slides prepared are to be received by the Commission no later than January 15, 1985 and are to be transmitted direct to the Co~ission and not examined by outside parties. , ~ Ail residue and excess sample material is to be returned to the Commission; no slide or sample material is to be retained by DGGS. No other thin-sections or slide are to be prepared from this material nor other analyses conducted without specific prior consent from the Commission. 7. DGGS shall bear all costs entailed. We are pleased.to work with you in this beneficial project and look forward to your continued exercise of care and good judgement in the handling of this limited quantity of valuable well material. I know we both understand that the State's well sample library is public property and granting DGGS permission to extract portions of material from this library for the purpose of preparing the subject material enhances the value of the library and is in the public interest. Sincerely, }.iichael T. Minder 'Petroleum Engineer lc:A.4e.22 Return signed and dated copy of this agreement. Signed Dated i i i i i ii, : i ,i i [ i i'll i1111 __ ,' 7 "~" ' ' ii_,:. .... ;'.: ......... '.i.~'..~'¥.:.~.i. '~.,.-,.:. ~,Z' , -~ .... · June: 4· 1952' :"~":'~ A~ ~ploratton ~,, Inc, ~': "' ? P '~' O; Box 360 ...... ~ ' " Anohorage, Alaska~99510- Geologic Slides and Analyses Prepared fro~ State ?,'ell .- '-~,- Samples and Core ~Chips, _ - :-~-:_:The~.enclosed-list reflects various ~eolo~ie slides and analyses that have-been recently added to ~he ~tate*s library of special materials prepared from well samples and core chips filed with the C~t.sston, The materials listed are in addition to those tabulated in the 1980 Statistical Heport and those reported in the" February, f~iarch and April 'monthly bulletins, Please photo-copy and distribute'copies of this list to appropriate persons within your company'.~/.. You" are the only person in your ,company '~to~iwhom ..:the.: 1 i st has been. sent. tn-:the"event publioation of the Co~nission's monthly bulletin, is not resumed, the::.next listing of newly received ceolo~ic materials will be distributed approximately September 1, 1982, For current information on newly'received materials please call the Commission office at any time, weekdays 8:00 A~,i to 4:30 P?~!, Alaskan Time, ALASKA OIL AND GAS cONSERVATION COMMISSION · · . June , 1982 samples and cores of wells drilled in the State. These materials are in addition to those tabulated in the 1980 Statistical Report and those reported in the February, March and April Bulletins. . . Foramini~fera S~p:l e~- . .~' ~.~.-~- - ~e~ ~h-~hedral Riv. U. ~1 89 50 - 14,360 Palynologie Slides - S~L Naptowne Unit ~24-8 13 14,600 - 15,226 S~OC~ Soldotna Cr ~22-32 19 13,640 - 14,560 'Themal~ A1 terat ion/Kerogen -~'.}~z'..,C:-s~L:.:Naptowne' Oh'it ~2~28.L4',:-;:~':?:~:;-~¢~/~//. 4'~.:~' '' ~ .... 14"600 15,226 Th~n-Seet~ons of Core Chip~-~?~: --M0bil-Kaal;~} St. ~15~926- : "11 9644 - 9695 Thin-Sections of Ditch S~ples Great. Basins Ug~'~hikV~i~ ~ 14 ~:~.~ .:' General,-·Petroleum Great'· Basins #2. .37. ~ Gulf"Sandy~River #1 '" . ".,.i, . 2 :?~: .::i~:' :?~:'?'. i pan ':'Ame'r i can .iDav i d:'-R i ve r? # I~-A:?;+::;':;''''':'' ':~" 3 4'" ':~::~.~;~:~:-'~' ~.'Pan.~e r i can:.HoodoO Lake '~ 1L' '..' 34 /{~: ~;~-?." :~-'.' V i t r in i t e "Re f 1 ee t ante ' S 1 i de s / P 1 ugs ?~:i~(~-.:~,~-:~'77{ Mobi'l::~-W:".:..stain~e~' ~2 -. /-'- . . .-- ~ · 48 --' ~ Texaco W. Kavik ~1 44 (:::~:~'. ' Exxon Canning River B-1 39 AR~ Kavik ~1 37 · .. - Forest.Kemik ~1 37 . _ g,-~ ":..' . Exxon Canning River A-1 _ '::: :..'~: ' 11 ~... Thermal Ma u at.~o... Reports ?~}~i);~!~-~:.~..¥'~- ~ gePort 'on ~total': .Organic Carbon-"' ;~': ' :;~:,~.~:-,-.'~' ,.'....'.:;~ and~.:Vi.trinite Reflectance Values ,: ' '~ for. eight North Slope wells ~...~.~ . . . .,~-..; ....... Report on Roek-Eval data:' for '--~-- ~:~,. · , 2400 - 4490 2210 - 8810 . .6280 - 8180 1350 -:4760 2480 - 8O5O 1020 - 13,150 1590 - 16,530 1040 - 10,800 560 - 9500 710 - 10,000 3750 - 5250 · 530 - 6500 1359 analyses 320 analyses ,March 31, 1982 Mr. Joe Curiale Union Oil ComPany of California 376 South Valenia Avenue B'rea~ California-~92621 Ceochemical Analyses on Samples and COre Chips from State Well Sample Library Dear Mr. Curiale: pursuant to our March 5,..1982 phone conversation and your discus- sions with Commissioner Kugler March 17 nd 18, 1982, permission has been granted to Union Oil. Company of Calfornia.to extract a maximum of 1 cc. of sample material per sample envelope, or 1 cc. of core material per foot of core, from the State's set of samples and cores for the purpose of conducting the following analyses and submitting the indicated material within the designated intervals in the follo%~ing wells, subject to the below listed conditions: AMAL YSE S - Total Organic Carbon (TOe) - Rock-Eval Pyrolysis (RE) - Vitrinite ~eflectance (VR) (~-?ot".to be done on ARCO Toolik Fed. $1) Your March 24, 1982 letter to Harry Kugler indicates the approximate number of the analyses to be run on each well. SAMPLE SET NO. WELL I NTE RVAL 345 248 337 240 299 342 322 204 Mobil.W. Staines $2 Texaco W. Kavik 1 Exxon Canning River $B-1 B.P. Eemik Un~t--~2 Exxon .Canning. River Unit #1 ARCO Toolik Federal .%1 2,800'-13,170' (183 samples) 330'-16,613' (105 samples') 800'-10,800' (190 samples) 400'- 9,559' (168 samples) 700'-10,000' (178 samples) 500'- 8,870' (128 samples) 1,170'- 8,880' (160 samples) 10,140'-10,230' ( 20 samples Joe Curiale ~. 2 :'-~':ch 31, 1982 - TOC, RE and VR data on akove wells in report form - VR Plugs CONDITIONS 1. Cuts of the samples and core chips from the State library set are to be extracted only from those individual envelopes or bags in which total content of samples or core chips is greater than 10 cc. (No cuts are to be extracted if the volume of material in the individual envelope is less than 10 cc. } :.2'.~. -'Union will provide the State with a list of the depths in the well from which material ~'as extracted. (This condition has been met by our-receipt of the memo you prepared ~,~arch 18, 1982, copy enclosed). All reports and VR plugs prepared are to be received by, the Commission by approximately ~ay 14, 1982 and are to be transmitted direct .to the Commi~sion and not examined by outside parties.- ~ll residue and excess material is to be returned to th~ 'Commission. 5~ No additional slides are to be' prepared nor analyses 'made on the sample or core war.rial without specific ~on. sent from the Commission. 6. UniOn ~.hall bear all costs entailed. . We are. pleased to work with you in this beneficial'project and look forward to your company's continued exercise of care and good judgement in the 'handling of this limited quantity of valuable well material, i I know we all underztand that the State's well sample library 'i.~ public property and that granting Union permission to extract portions of ~aterial from this library for the purpose of preparing the indicated reports and VR plugs enhances the value of the library and is in the public interest. Very truly yours, · William Van Alen Petroleum ~eol~ist cc: Mr. J. A. Packard- Union, Anchorage' WVA/glh February 2, I981 Mr. William G. Reay Union Oil Company of California 2326 Knoll Drive Ventura, California 93003 Re: Slides from State Samples - Forest Kemik Unit #1 and ARCO Nora Fed. #1. Dear Bil 1, For reference, please take a look at my May 23, 1980 letter to you pertaining to Union's preparation of various slides from samples of the subject wells. In talking on the phone today with Bob Ballog, I learned that petrographic thin sections will not be prepared from the 15,200' - 16,940' interval in the ARCO/Home Nora Fed. #1. Therefore, I can stop waiting for receipt of these thin sec- tions. Accordingly, since all slide and residue material has been received on the. two wells, the project is considered closed. I write this as a matter of record. The foram, paly and petrographic slides contributed by Union on these two wells are valuable contributions to the Commission's well sample and core library and you, Bob, Clark Weaver and your respective associates are thanked sincerely for your work in implementing this beneficial project. William Van Alen Petroleum Geologist Enclosure cc: Mr. R. A. Ballog Mr. J. A. Packard October 7, 1980 Mr. Mark Spangtet Cities Service Company P.O. Box 27570 HOuston, Texas 77027 Re: Thin-sections of ditch samples-Forest Otl Kemik Unit Dear Mark; Receipt is acknowledged for the following thin-sections of the subject well missing from the shipment received July 24, 1980~ 8680' - 8740' 8740' - 8840' 8840' - 8870' 8870' - 8950' These slides were received October 6, 1980 and complete the conditions of the thin-section preparation agreement set forth in my February 22, 1980 letter to Harold W. Baker. Sincerely, William, Van Alen Petroleum Geologist August 13, 1980 Mr. Harold W. Baker Cities Service Company P. O. Box 27570 Houston, Texas 77027 Res Thin-sections Of ditch samples- Forest Oil Kemik Unit #1 Dear Hair In checking over the slide material you sent up here last month, I note that we lack the' thin sections prepared from cuttings of the following intervals in the subject we11~ 8680' - 8740' 8740' - 8840' 8840t - 8870' 8870' - 8950' The enclosed transmittal letter corrects, our August 6, 1980 letter covering the material received on this well. Samples were cut from the State set of samples in these intervals and we have received the 4 plugs you prepared but the thin sections were not received. Please take a look around your facility and see if perhaps these 4 slides might have been inadvertantly tubby-holed somewhere and missed being sent to Sini_~ely,.i~.~~. Wi11lam VaD~len Petroleum Geologist August 13, 1980 Mr. Harold W. Baker Cities Service Company P. O. Box 2'7570 Houston, Texas 77027 Res Petrographic thin-sections, Alaska wells Dear Hal= ReCeipt is ~ acknowledged for the fol lowing petrographic thin-sections and residue material hand delivered here July 24, 1980 by Messrs. Humphreys and Hull of Citco's Houston office: Samples: 50" slides 4400' to 8620' Cores: 28 slides 8622' to 8680' Pan Ameri~ Kavik Unit #1 & #LRD Samples: 8 slides 4250' to 4550' British Petroleum Kemik Unit #2 Cores: 29 'slides 6160' to 6224' Atlantic Rid~field Co. Kavik Unit #3 Cores: 15 slides 4945' to 5440' Samples~ 19 slides 4910' to 5220' Standard Oil Co. of California Kavearak Pt. #32-25 Cores ~ 18 slides 6908 ' to 6967 ' The above material along with material received here June 3, 1980, is received in connection with the agreement set forth in my letter of February 22, 1980. Sample sets 309, 285, 208, and 248 have been deleted from the list of wells covered in the agreement. very truly yours, William VanAlen, Petroleum Geologist R. E. Elkins Citco - Anchorage 8/12/80 corrected depth. August 6, 1980 Houston, Texas 77027 Receipt is a~l~ i~ m~~ of ~~'s ~ offi~ Cores: 28 slides pan Bri~ ~~~ ~ ~t %2 A~~c .~~~ ~. ~ ~t %3 ~~s: 19 s~s s~ ~s: "4400' %O 8950' 8622' tO 8680' 4250' to 4550' '6160' 'to 6224' 4945' to 5440' 4910' to 5220' Pt. #32-25 i8' s~S .............. 6908' %0 6967' ccmpletes the ~t set f~ ~.in my letter of February 22, 1980. Sample sets 309, 285, 208, and 248 have..~, ,deleted .from the list of w~lls ~ in the ~t. William VanAlen, Petrole~ Geologist cc: R. E. Elkins ~ ~ . . May 23, 1980 slides Mr. William G. Reay Union Oil Cc~pany of California 2326 Knoll Drive Ventura, California 93003 Dear Bill: Acq~sition of drill cuttings and core chips for preparation Pursuant to my re(~ discussions with you, John Packa~ and Clark ~aver, permission is hereby granted to Union Oil Company to make small quantity cuts (approximately one cc. max~ each) from the State's set of samples and cores for the purpose of preparing the indicated slides for 'the State sample library within the designated intervals in the following wells, subject to the conditions set forth below: Sample Set No. 299 Slides to be made Forest Oil Corp. ~Xemtk unit #lc Foram/Radiolaria Samples Palynological (2 sets) & Kerogen Slides Thin Sections (Selected intervals) 700'-16,073' 700'-16,073' 8900'-16,073' 263 ARGO/Home Nora Fed. #1: Forsm/Raliolaria samples Palynological (2 sets ) & Kerogen slides Thin sections (Selected intervals) 2720'-17,520' 2720'-17,520' 15,200'-16,940' Cuts of samples or cores are to be made only out of those individual envelopes or bags in which the total volume of cuttings or core material is greater than 10 cc. No cuts are to be extracted if the .volume of material in the individual envelope or bag is less than 10 cc. Union will provide the State with a list of the specific sample and core intervals frc~ ~ich material was extracted. Union shall bear all costs entailed and will provide the Alaska Oil and Gas Conservation Commission with a complete set of all slides prepared and return all remaining .sample and core residues. No slide or rock material is to be retained by Union. Two sets of palynological slides are to be prepared, one of which will be received by the C~mnission by apprcx~tely August 1, 1980. Conservation Commission with a complete set of all thin sections and return all remaining sample and core residues. No sample or core material is to be retainea by CITCO. .All thin sections prepared from these cuts are to be received by the Commission no later than June 1, 1980. It is mutually understood that the State ts well sample library is public property and that granting CITCO permission to extract portions of the materials from this library for the purpose of preparing thin sections is in the public interest. We are pleased, to work with you in this mutually beneficial endeavor and look forward to your company's continued exercise of care and good Judgement in the handling of this well material, as evidenced in the sample processing arrangements CITCO has undertaken with the State in the past. very truly yours, .. William Van Alen Petroleum Geologist CC ~ R. E. Elki.~.~, .. Citco -Ancho. rage February 22, 1980 Ret Acquisition of Drill Cuttings and Core Chips for Pre,ration of Thin Sections Mr. Harold W. Baker Cities Service Company P. O. Box 27570 Houston, Texas 77027 Dear Hal: In response to our discussions this week with you, Joe Davidson and Mark Spanglet,~.permission is hereby granted to Cities Service Company to make small quantity~u~s' (a~proximately one cc. maximum each) from the State's set of samples and bOr~s of the following wells for the purpose of preparing thin sections, subject'to the conditions set forth below~ Set No. Well Interval · '10,060'-10,700' Colorado Yakutat #3 *(thin sections to be prepared on site at Commission office) 17-A Colorado Dangerous River #1 1,900'- 7,900' 40 Colorado Malaspina #i-A 12,990'-13,020' 240 Atlantic 'Richfield Kavik #1 4,250'- 4,580' 309 Atlantic Richfield Kavik #2 4,670'-.6,240' 321 Atlantic Richfield Kavik #3 4,120'- 5,600' 299 Forest Kemik ~1 3,560'- 8,900' 342 British Petroleum Kemik ~2 .. 6,160'- 6,225' 285 Atlantic Richfield W.Sak Riv.%l 3,720'- 6,680' 238 Chevron Kavearak Pt. ~32-25 3,700'- 7,130' 208 Sohio Ugnu #1 6,130'- 6,270' 248 Texaco W. Kavik 13,150'-13,480' Cuts are to be made only out of those bags in which the volume of cuttings or core material is greater than 10 cc. No cuts are to be extracted if the volume of material in the State set is less than 10 cc. Even though the above intervals may overlap intervals within which thin sections are currently on file in the State collection, no thin sections will be prepared that duplicate the specific footages coverudby existing slides. CITCO will provide the State' with a list of the specific sample and core footages sampled. CITCO shall assume'all costs entailed and will provide the Alaska Oil and Gas ~ FOREST OIL CORPORATION 1000 ~J~ecur~l~t o.~'ife '~-~u~ld~ft. ~o~f)enve~; ~o/orado 80o_0~ August 2, 1972 CONFIDENTIAL' i ,, CON Ft DENTi AL ,, Mr. Homer L. Burvell, Chairman State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir' Attached please find two copies of Form P-7 Well Completion for our Kemik Unit #1 Well located in Section 17, T1N, R2OE, North Slope, Alaska. Very truly yours, FOREST OIL ~RPORATION H. E. Snider Division Production Manager HES/ls Encl. DIVISION O? SUBMIT IN STATE OF ALASKA AND ~A5 CONSERVATION CO~ITT~E i - ~ - ..... :E~:-- _ _ : .-- ' · '-- i iii WELL EOMPLETION OR REEOMPLEIION REPORI AND LOG ................. i i i ii b. TYPE OF COMPLETION: ' ' W EI.i. OVER ~ EN ~ B&CK ~ i~E S%' R. , , , ~ N'~ME OF OP~RAT9~ FOREST OIL CORPORATION ~.~,~ o~ o~...~o~ 1600 S~cu~itv Life Building 4. LOC~TION Ob' WELL ~Report ...... Ioc~tio~ ~early~r and in accordance wltA any State requirements)* at,~,¢, 2396' VEL 2073~ FSL Sec i? TiN R2OE CONFIDENTIAL - Same a8 SUrface, Uncontrolled Vertical H61e 70-60 1 Ban 1971~19 May 1972 1.7 3une 1972 123~ RHB-MSL .20" / j ~O~V ~NY* 16073 ~D ~ TVD j9156 MD ~ TVD j. Sinqle 0-16073 [ -- ~. P~ODUCING [N~RVALiS~ OF ~IS CO:~IP~TIO~--TOP, BOSOM, NA~IE (~ AND ~)' 1 ~, WAS D(~ECT!ON&L 5hublik Lime 8664-8800 MD & TVD , ~. APl NL~.' G'~i~ 50-223-20006 6. L.~SE DESIGNATION Fairbank~ 021270 ~one ....... Kemlk Unit ~. W~ NO. 10. FIE~ aN'D POOL, OR Wildcat h. SEC., T., ~., M.. ~BOTTOM o~mv~ See 17 Tl~ R2OE, Umiat Meridian 24. TYPE ELECq'EIC AND OTH~. LOGS ]RUN Schlumberger; DiL, Densitv-SR, Sonic-GR, CSL,Oipmetar Survey ' , - . . :. ~ ~ ~ ....... ~ ........ SCiLE~ ,~ID~ i ..i~E [ DEPTi. SET (~.lg, ~ :1 v~'~o.S, is~ss.bo I550 ' '-- I ...'~' i ..... ',, i ,,". _7, ,.,~7E [ ' ........ , It !i ............. , . - 25 May 1972 O~en Hole DST No. 3 - Flowinq J Shut-In [ . I ITE.i~ dk;!tlOD } ! + I~mss: · J [~4-itou2 ~.~ I Z~9-asooosil ' O I -" > [. O .... I 5-1O.OOO I Q ] ~o,~ .... Vented ~ Flared [W. C. Wunntcke. USGS ~2, [.I~T OF a'rrtcH~ttNIs Summs~v ar Opera.~ions; Logs g Samples Submitted Separately; l'e~t pate Sheet , .. /~~~~ ..... DIVISION FRODUCTION MGR. ~, 7 /.~Z ..... ~~' .... u ~ ................ ~ ~ ~. · (See Instructions mn~ S~ces [o~ A~gifion:[ D:~o on Reverse Sige) INSTRUCTICiN$ General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in c, ther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc production from more than one interval zone .... (multiple completion), so state in item 20. and in item 22 show lhe p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reporled in item 30. Submit. a separate report (page) on this form, adequately identified, for each additional inte~ val to be separately produce~, show- lng the adiditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). '34. $'UMMAltY OF [.'()RMATION T~L'.ST,",i IN('I,UI)IN(~ INTI:HIVAL TE..qTED, i)!1 'DqSI. Jll£ DATA AN'D ~OV~ltlF-,S OF (')IL. GAS. WATET~ AND MUD Shubltk Formation DST No. 1 - Open Hole Test - Packe~ Failed - No Test DST No~ 1~ - Open Hole Test - Packer Failed - No Test DST No. 2 - Open Hole Stmaddle Test Interval 887~-B?1~~ IHP 5D60; IFP 1N minutes, 1538: ISIP 80 minutes, ~8: FFP 3~0 minutes, FSIR 60 minutes, N~98: FHP NB?~ ~02~ Estimate i~MMCFD from Choke Data - Dry Gas 3~. ¢'OI1.E DATA. A'I~I'ACI[ llHIEF' DgC~IPI~ONS O~ LITt[OLOGY. POHO~iT¥. F[IAC~, ~ '~kRlr~ ~J-~ Gore No. I Core ~O. 2 B62'2~-78e Recovered 5G~ B622-3B~ Shale 8638-~3 Shale & Limestone 86~3-78~ F~actured Limestone - No Shows 1099~-110~ Recovered 50~ Limestone with no shows NAM~ Okpikruak Kingak Shale Kemik Ss ½ingak Shale Kemik Ss ½ingak Shale ½emik Ss ~ingak Shale Sa9 River Ss Shublik Li Sadelerochi~ Lisburne Li ~ayak WIEA$ D'ET~Tlt 0 2000e 2~20e 2510~ 3507v 3B50~ ~33~ ~730~ 851Be 8538~ BB30! 10950! 1596B~ 'l'E U~ V£11T. _ Measured Depth g True Vertical Depth approximately sase-- Depths are RK8 CONFI ENTi/IL TEST DATA SHEET Attachment to Alaska 0 & G Conservation Committee Form P-7 WELL COMPLETION REPORT & LOG ½EMIM UNIT NO. i FOREST OIL CORPORATION 1600 Security Life Building . - ~ontinu, Shublik ~Formation Tests LETION REPORT & LOG HWPT No~ 1 Hookwall Packer Test w/Packer Set ~ 8745' inside 7" OD Liner - Perforations 8780-8800 - Test Tools Plugged - Test Inconclusive HWPT No. lA Same as above w/Packer ~ 8714' HWPT No. lB Same as above w/Packer Set ~ 87037 IHP ~849: IFP 5 Minutes, 1046: ISIP 127 Minutes, 4535: FFP 155 Minutes, 859, 2.05-2.14 MMCFD, FSIP 165 Minutes, 4569: FHP 4800 - DrV Gas with no liquids HWPT No. 2 Hookwall Packer Test inside ?" OD Liner w/Packer Set ~ 8609'-Perforations 86G~' to 8800' IHP 5209: IFP 5 Minutes, 2428: ISIP 135 Minutes, ~559: FFP 360 Minutes, 1957, lOJ4 HMCFD, FSIP ~20 Minutes, 4559: FHP 5215: BHT 213°F: Flowed Drv 6as - Recovered Mud Filtrate from Test Tools CONFID 'NTIA[ 1-5 2an. 1971 6 2mn. 1971 8-11 Feb. 1971 12-15 Feb. 1971 16 Feb. 1971 17-19 Feb. I9?i 20-21 Feb. 1971 22 Feb. 1971 SUMMARY OF OPERATIONS Attachment To Alaska O&G Conservation Committee Form P-7 WELL COMPLETION REPORT & LOG MEMI½ UNIT NO. I FOREST OIL CORPORATION 1600 Securitv Life Building D Colorado 60202 DRILLING FROM SURFAC Spuded on 2anuarv 1, 1971-and drilled 36" Conductor Hole 'from surface to 58' below ground level with a Bucket Rig. Twisted Bucket Rig HellV. MOVED OUT BUCHET RIG AND MOVED IN BRINHERHOFF DRILLING CO. Rig No. 1 Brinkerhoff Drilling Companv's National Ideal TvPe llO Rotarv Rig was moved in and rigged up with its suxilliarv equipment. SET 30" OD CONDUCTOR CASING AND CEMENTING Set 30" OD Conductor Casing at 58' and cemented in (3) Stages to surface with 154 sx of Fondu Cement: W.O.C. Finish rigging up. DRILLING FROM 58' TO 570' 17~" HOLE ½. B. elevation above ground level: 14.4 Ft. Drilled with l?~" Bit and 26" Hole Opener below 30" OD Conductor to 86'. Drilled 17~" hole to 570'. Mud: 9.0 ppg Vis 55 DRILLING FROM 570' TO 70fi' WITH 12%" B Drilled 12%" hole from 570' to 706'. OPEN HOLE 12%" & l?~" HOLE TO 26" DIVISION O~~ ()~I...: ~,~, ('-:..~'~ Open 12~" Hole to 17~" to 700' Open 17~" Hole to 26" from 86' to 694' Mud: 9.0 ppg Vis 60 - Deviation of Ol°15' ~ 670 RUNNING 20" OD CASING AND CEMENTING Circulated to condition mud and hole for casing. Pulled out driliing assembiy and Iayed down. Rigged up and ran (i7) joints of 20" 0D,.i33.33 ibs/ft, ½-55, Buttress Casing. Landed at 688.83 R.½.B.. Cemented casing with iN?O sx Fondu Cement~from bottom to surface. W.O.C. 2N hrs. RIGGING UP 20" WELL HEAD AND BOPE Cut off 20" casing and installed 20"-2000 psi W.P. Casing Head and 2000 psi W. P. Hvdril 8DPE. Rigged up Flow Line & ½ill Line. Pressure tested 8OPE and casin9 to 1DO0 psi, for , .ou . CONFIDENTI, AL 23 Feb. thru 5 Mar. 1972 6-12 1971 13-15 March · 1971 16 March 1971 17 March 1971 18-27 March 1971 28 March thru 5 April 1971 6-12 April 1971 13 April 1971 14-15 April 1971 16-17 April 1971 KEMIK UNIT NO. 1 DRILLING FROM 20" CASING POINT TO 2700" Prill Float Collar and cement to Float Shoe. Pressure tested _O" OD Casing to 1000 psi for % hour. Drilled Float Shoe and drilled 17~" hole to 855'. Reduced hole size from 17~ %~ 12%" and drilled to 2700'. Mud: 9.5 ppg Vis 36 Deviation: 1-15' ~ 850' . CONFIDENTIAL OPEN 12~" HOLE TO 17~" Open 12%" Hole to l?~" from 85~' to 2700'. Mud: 9.7 ppg Vis 75 W1 18.5 - Deviation: 02-30' @ 2700'. RUNNING 13 3/8" OD CAS.INS AND CEMENTING Circulated to condition mud and hole for casing run. Run (66) Joints of 13 3/8" OD, 68 & 61 #/ft, ½-55, Arctic Grade, Buttress Easing and landed at 2670' RMB. Mixed and pumped 3800 sx of 100% Fondu Cement. No cement return to surface. .Run l" OD XH Line pipe in 13 3/8" X 20" Annulus to 369'. Circulated mud out and mixed and pumped N?O sx of 100% Fondu Cement. Good cement returns (120) ax.- Landed 13 3/8" OD casing in 20" casing head. Pressure tested casing head seals to 1200 psi. Installed 20"-2000 psi WP X 12"-3000 'psi WP spool and 12"-3000 psi WP Double Ram and Annular Hvdraulic BOPE. DRILLING OUT OF 13 3/8" CASING Cleaned out cement from 13 3/8" OD casing and drilled out Float Collar. Pressure tested casing and BOPE to 1300 psi. Drilled out Float Shoe and hole to 2704'. Drilled on junk in 12~ hole below casing. (17~" Hole Opener Cutter) TEST BOPE Tested all the BOPE's and Choke Manifold with 3000 psi. Milled up junk in the hole and recivered small pieces of junk with Globe Basket. DRILLING 12%" HOLE Drilled 12%" ~ole from 2709' to 4390'. Mud: 8.7 ppg Vis 36 Deviation: 04045, @ 4340' - Tested BOPE's and Choke Manifold with 3000 psi Drilled 12%" Hole from 4390' to 5811'. Tested BOPE's end Choke Manifold with 3000 psi - Deviation: 03-15' ~ 5776' Drilled 12%, Hole froTM 5811' t~ 7706' - Tested BOPE'sand Choke Manifold - Deviation: 05-15' @ 7706' - Mud: 9.7 ppg Vis 58 WI 3.5 Circulated to condition hole and mud to log. LOGGING & SETTING PLUG @ 7706' Run Schlumberger DIL Log. Set cement plug from 2386' to 2942' (580 sx Neat API G Cement). Tag cement plug ~ 2366'. Closed pipe rams and pressure tested cement plug with 500 psi surface pressure. ~%& Irl~r& l~lll SHUTTING DOWN FOR SUMMER I.'N~I'~N/IA/ Displace 13 3/8" casing with diesel oil. LeV. down dril1- pipe. Shut rig down. Stack equipment and materials fo~ sdmmer shut down. Rig release at 12:00 hours - April l~, 1971 SUMMARY Page 2 17-22 Nov. 1971 23 Nov. 1971 24 Nov. thru 24 Dec. 1971 25-26 Dec. 1971 27-31 Dec/, i97i / 1-4 San. 1972 5-10 Dan. 1972 ll-12_'Oan. 1972 13-24 San. 1971 25 Jan. 1972 26-31 San. 1972 RE-ENTERING HOLE Go in Hole with 12~" Bit. Stopped ~ 358~. Run 9 7/8" Bit to cement plug ~ 2386'. Displace diesel with mud. Swage out 13 3/8". Casing from 357' to 360'. Pressure Test 13 3/8" Casing with 500 -2000 Psi for 20~ hrs. Casing leak after 6 hfs ~ 2000 psi. Drill cement with 12%" bit from 2386 to 2956. Mud: 9-8 ppg Vis 76 Clean out open hole below 13 3/8" Casing. Drill out bridges and circulate out sloughing shale. Operations partiallv shut down due to weather & lack of water for intermittant LOGGING @ 7706' Condition hole & mud for Logging. Run Schlumberger Dipmeter Survev, Sonic Log, Densitv Log from 13 3/8" OD Casing Shoe 'to TD RUNNING & CEMENTING 9 5/8" OD CASING ~ 7711' Condition hale and mud to run Casing. Drill 12%" hole to 7711'. Run 9 5/8" OD Casing: (30) joints 47.00 lbs/ft. S95, Buttress; (158) joints, 47.00 lbs/ft N80, Buttress, casing Total Length 7710.39'. Casing landed ~ 7708'. Casing equipped with Float 3hoe, Float Collar, Self-fill Differential Collar, DV Stage Cementing Collar ~ 2787' & Casing Safetv joint ~ 1798'. Cement 9 5/8" OD Casing thru shoe with 1160 sx Class G Cement. Open DV Stage Cementing Collar. Mix & pump 150 sx Class G Cement. Close DV Stage Cementing Collar & pressure test @ 3000 psi for 30 Minutes. Install 12"~3000 X 10"-5000 Casing Spool. Install 10"-5000 Double Ram Hydaulic BOPE w/Blind Rams & 5" D.P. Rams, 10"-5000 Annular Hvdraulic BOPE, 4X2"-5000 Choke & Mill Manifolds. W.O.C. PREPARE TO DRILL 8~" HOLE W.O.C. Complete installation of 4"X2"-5000 Choke & Mill Manifold. Test all BOPE to 5000 psi for ~ hour. Pick up BHA & go in hole. Drill cement & DV Collar from 2777' to 2788'. Drill cement plug from 7189' to bottom of Float Shoe & Cement ~ 7110'. Treat cement contaminated mud. DRILLING 8~". HOLE Dr~ll from 7710' to 8168'. Mud: 10.2 ppg Vis 110 - Deviation: 09-00' ~ 8168'. CONFIDEN'I'IAI. Drill 8~" Hole to 8622'. Deviation: 07045' ~ 8594' CORE NO. i Trip for Core Barrel. Cut 8 15/32 X 3~" Core from 8622' to 8679'. Recovered 57'. Drill 8~" Hole to 8825'. CirculateL& condition hole & mud' for DST. Mud: 10.7 ppg Vis 100 wl 4.'~ - Deviation: 07°15' @ 8817'. HEMIH UNIT NO. 1 SUMMARY Page 3 1-2 Feb. 1972 3-18 Feb. 1972 19-29 Feb. 1972 1-15 March 1972 16-21 March 1972 22 March 1972 23-31 March 1972 1-11 April 1972 12-15 April 1972 16-30 April 1972 1-5 May 1972 6-19 May 1972 20-2N May 1972 25-26 May~: 1972 DST NO. 1 P.OoH. Run Drillstem Test Tools, 1900' of water cushion & set packer ® 862N'. Open tester &~packer failed. Made hole conditioning trip. Run DrillStem Test Tools Packers for DST No. lA. Set ~ackers ~ 8633' & 8639'. 'Ran 2000' Water Cushion. Opened tester & packers failed. P.O.H. Go in hole & condition hole to drill ahead. DRILLING 8~" HOLE CONFIDENTIAL Drill to 9539'. Test BOPE to 5000 psi. Deviation: 09030, ~ 9350'. Drill to 10,063'. Test BOPE ~a 5000 psi - Mud: 10.7 ppg Vis 63 W1 4.4 - Deviation: 05-15' ~ 9798'. Drill to 10,800' - Deviation: 02045, @ 10,450'. Dr~ll to 10,994'. Mud: 10.6 ppg Vis 83 Wi 4.2 - Deviation: 03-00' ~ 10,925. CORE NO. 2 Run 8 15/32 X 3~" Core Barrel. Core from 10,994'to 11,044'. Recover 50'. Drill to 12,080'. Mud: 10.7 ppg Vis 75 - Deviation: 03°00' @ 11,889'. Drill to 13,050'. Condition Hole & Mud to Log. Mud: 10.8 ppg Vis 84 - Deviation: 05-45' ~ 13,010' . LOGGING P.O.H. Run Schlumberger Dual IGduction Laterolog. Sonic- Gamma Ran, Density-Gamma Ray & continuous (4) Arm Dipmeter Logs. Trip to condition mud &hoie. Run United Geophysicai Corp. Veiocity Surveys on Schiumberger Line. DRILLING 8~" HOLE Drill to 1N,3OG'. Mud: 10.7 ppg Vis G7 - Deviation: 02045, @ 14,30G'. Drill to 14,707'. Test BOPE to 5000 psi. Drill to 1G,073'. Mud: 10.7 ppg Vis 90 - Deviation: 03000, @ 16,073'. Reached Total Drilled Depth this date. Prepare to Log. LOGGING @ 16,073' TD Make Trip, circulate to condition mud & hole for logging. Run Schlumberger Dual Induction Laterolog; (4) Arm Continuous Dipmeter Survey; Sonic-Gamma Ray; Density-Gamma Ray from 13,050' to T.D. OPEN HOLE DST NO. 2 /' AiJ, II Ihl-i ITIiIL, ur, Ii..iUEN'/mj.._., j,. Circulate to condition hole & Mud for drillstem test. Run Lynes Inflatable Straddle Packers & Test Tool Assembly, with 2200' water cushion. Set Packers @ 8679' & 8719'. Conduct drillstem with Initial Flow, Initial Shut-in, Final Flow & Final Shut-in periods, for 8~ hours. Unseat packers & pull Test Tool Assembly out'of hole. Recovered 210' of slightly gas cut mud & no other liquids. Mud: 10.7 ppg Vis 70 ½EMIH UNIT NO. 1 SUMMARY Page SET OPEN HOLE CEMENT RLU6S 27-29 May 1972 ~ Measure open ended drillpipe in hole to 13,50!'. Circulate .o condition mud & hole. Mix ~ Pump 100 sx Class 6 Cement + 0.5% DBR Retarder. CIP ~ OlO0 hrs., 5-28-72. Pull up ~ole, measuring drillpipe to ll,lOl'. WOC 5 hrs. Mix & pump 100 sx Class G Cement + 0.5% D8R Retarder. CIP ~ 0900 us. 5-28-72. Pull out of hole. 30-31 May 1972 .Measure open ended drillpipe in hole to 9429'. Circulate to condition hole & mud. Mix & pump 150 sx Class 6 Cement + 0.21% DBR Retarder. CIP ~ 0030 hrs., 5-29-72. Pull out of hole. WOC 8 hrs. 6.I.H. with BHA to 7708'. Circulate & condition mud..:.G.I.H. & Tag Cement Plug ~ 9158'. Firm Cement. co CONFIDENTIAL Circulate to condition mud & hole. P.O.H. Run (42) joints of 7" OD, 29.00 lbs/ft., 480, Buttress, Range 3 Casing (Liner); equipped with Shoe, Landing Collars, Liner Hangar & Tie Back Sleeve. Total Length 7" OD Casing 181D.34'. Top of Tie Back Sleeve ~ 7340.84'. Bottom of Liner ~ 9158.00'. 30-31 Nay 1972 Set Liner Hanger. Mix & Pump 50 sx Olass G Hi-Vis Cement followed by 500 sx Class G Cement + 0.10% DBR Retarder. CIP ~ 1030 hrs., 5-31-72 W.O.C. 24 hrs. 1-30une 1972 COMPLETION PROCEDURES Continue W.O.C.. Tag tap of Liner ~ 7339'. P.O.H. Pick up 6" Bit & 2 7/8" EUE, 480, 6.50 lbs/ft. Tubing & measure in hole. Tag top of cement in 7" OD Liner 9 8819'. Drill cement to 8863'. Circulate, treat cement contamination out of mud. N 3une 1972 Run Schlumberger CBL-Gamma Ray Log from 7100' to 8863'. Run Retrievable Packer & Set ~ 7330'. Pressure Test Line~ to 2000 psi. Perforate interval 8780'-8800~ with Schlumberger Casing Perforator loaded~.with (~)-~" Hyperjets per foot. 5-6 June 1972 Run Retrievable Packer Test Tools on 2 7/8 EUE Tubing, with 2000' water cushion for Hookwall Packer Test No. 1.. Set packer ~ 8745'. Open Test Tool. Get immediate weak blow which died after 15 minutes. Close Test Tool for shut-in pressure. Unseat packer & POH. Water Cushion 15' high & mud cut. Test Tools plugged. Re-run same Test Tool Assembly for Hookwall Packer Test No. lA. Set packer ~ 871~'. Open Test Tool & get immediate blow for 8 minutes whiCh died. Leave Test Tool open 135 minutes. G'et no further blow. Close Test Tool .for Shut-in Pressure. Release packer & reset ~ 8681'. Open Test Tool for 85 minutes. No Blow. Release packer & POH. Found thick mud 15' above Test Tools. IHP 5022; IFP 4698; FFP 4779; FSI 5202; FHP 4941 - Mud: 10.5 ppg Vis 100 W1 4.0 7-90une 1972 HENIH UNIT NO. 1 Oiroulate& condition mud. Treat out cement contamination. Run Retrievable Packer & Test Tools on 2 7/8 EUE Tubing with 2000' of Wate~ Cushion for Hookwall Packer Test No. lB. Set Packer ~ 8703'. Open Test Tools for immediate strong blow. Tester Open 5 minutes for Initial Flow. Close Tester minutes for Initial Shut-In Pressure. Open Tester for Flow Period (1) for 266 minutes. Gas to surface in 2 minutes. Water cushion to surface in 19 minutes. Flow thru Test Separater Orifice.Meter Run. Open Tester for flow fo~'155 minutes ~ ~ates of 2.05-2.1~ MMCFD. Tester for Final Shut- In Pressure (2) for 165 minutes. Release packer & POH. Recovered 20' of apparent mud filtrate aboVe Test Tools. Bottom Hole Flow Tube size 7/8" . CONFID[N'rIAL SUMMARY Page 5 10 Dune 1972 e 13 Oune 1972 14 Oune 1972 15 Dune 1972 Dune 1972 17 Oune 1972 18-26 Oune 1972 Circulate to condition mud, Run Schlumberger Casing Perforator, loaded with (&)-~" Hvperjets per foot & perforate interval 8664'-8780'. Mud: ll.2 oPg Vis 63 W1 6.0 Run Retrievable Packer & Test Tools with 2000' of water cushion for Hookwall Packer Test No. 2. Set packer ~ 8609'. Open Tester for Initial Flow for 5 minutes, for immediate strong blow. Close Tester for Initial ShLJt-In Pressure for 135 minutes. Gas to Surface in l0 minutes, (while Tester closed). Open Tester for Flow Period. Water Cushion to 'surface in 7 minutes. F_.E~_low_..for~60 minutes,,~ rat~of lO.14 minutes.MMCFD' Close ~~~_f~r Final Shut-ln Pre~§ure for ~20~,~ble~e~~l~ Open circulating su string & reverse circulate to stabilize mud column. Release Packer & POH. Circulate to condition mud. Mud: ll.1 ppg Vis 58 W1 6.0 Set Baker Model N Bridge Plugs ~ 8596' & 8586' (wire line measurement) with Schlumberger wire line in 7" OD Liner. Tag top of Baker Bridge Plug ~ 8578'. In Hole with 2 7/B EUE Tubing hung ~ 8578' in 7" OD Liner. Mix & pump 50 sx Class G Cement + 0.2% DBR Retarder. CIP @ 0225 hrs. WOC 7~ hrs. Hang 2 7/8" EUE Tubing @ 7176' in 9 5/8" OD Casing. Mix & pump 100 sx Class G ~ment. CIP @ lll5 hrs. Hang tubing ~ 6745'-. 'Mix 175 Bbls. ll.3 ppg mud & displace down tubing. POH. Set Baker Model N Bridge Plug @ 26DO':in 9 5/8" OD Casing (Wire line measurements). Tag t~p of Bridge Plug 9 2587' with 2 7/8" EUE Tubing. Hang 2 7/8" EUE Tubing @ 2576'. Hix & pump 100 sx Class G Cement. CIP ~ 2400 hrs. POH. Remove BOPE. Run Casing Spear & engage 9 5/8" OD Casing @ 69'. Disconnect 9 5/8" OD Casing Safety joint 9 1798' R½B. Pull out &la¥ down (N2) joints, 1781.8~' of 9 5/8" OD Casing. GIH with 2 27/8" EUE Tubing to 1800~,.in 13 3/8" Casing. Hix 150 Bbls. of ll.2 ppg mud & displace down tubing;, POH. Mud Level standing ~ 55' RMB last 2N hours. Tea~ing Rig Down. Bolt ~" Plate on 12"-3000 X 20"-2000 Casing Spool with 8" Hole cut in center; 13 3/8" OD X 6' Long .Casing welded to plate with %" solid ~late welded to top. Well Shut-In Complete. Tear Down Brinkerhoff Rig No. 1. CONFIDENTIAL KE~IH UNIT NO. 1 SUMMARY Page 6 1-5 Dan. 1971 6 Dan. 1971 B-11 Feb. 1971 12-15 Feb. 1971 16 Feb. 1971 17-19 Feb. 1971 20-21 Feb. 1971 22 Feb. 1971 SUMMARY OF OPERATIONS Attachment To Alaska O&G Conservation cOmmittee Form P-7 WELL COMPLETION REPORT & LOG ½EMIM UNIT NO. I FOREST OIL CORPORATION 1600 Security Life Building Denver, Colorado 80202 Spuded on January 1, 1971-and drilled 36" Conductor Hole ~from surface to 58' below ground level with a Bucket Rig. Twisted Bucket Rig Mellv. MOVED OUT BUCMET RIG AND MOVED IN BRINMERHOFF DRILLING CO. Rig No. i Brinkerhoff Drilling Company's National Ideal Type llO Rotary Rig was moved in and rigged up with its auxilliarv equioment. SET 30" OD CONDUCTOR CASING AND CEMENTING Set 30" OD Conductor Casing at 58' and cemented in (3') Stages to surface with 154 sx of Fondu Cement: W.O.C. Finish rigging up. DRILLING FROM 58' TO 570' 17~" HOLE ½. B. elevation above ground level: 14.4 Ft. Drilled with 17~" Bit and 26" Hole Opener below 30" OD Conductor to 86'. Drilled l?~" hole to 570'. Mud: 9.0 ppg Vis 55 DRILLING FROM 570' TO 706' WITH 12~" BIT Drilled 12~" hole from 570' to 706'. OPEN HOLE 12%" & 17~". HOLE TO 26" Open 12%" Hole to 17~" to 700' Open 17~" Hole to 28" from 88' to 694' Mud: 9.0 ppg Vis 60 - Deviation of Ol°15' ~ 670 RUNNING 20" OD CASING AND CEMENTING Circulated to condition mud and hole for casing. Pulled out drilling assembly and laved down. Rigged up and ran (17) joints of 20" 0D,.133.33 lbs/ft, ½-55, Buttress Casing. Landed at 688.83 R.½.B.. Cemented casing with 1470 sx Fondu Cement.from bottom to surface. W.O.C. 24 hrs. RIGGING UP 20" WELL HEAD AND BOPE Cut off 20" casing and installed 20"-2000 psi W.P. Casing Head and 2000 psi W. P. HVdril 8OPE. Rigged up Flow Line & Mill Line. Pressure tested 8OPE and casing to IODO psi, for % hour. 23 Feb. thru 5 Mar. 1972 6-12 1971 13-15 March 1971 16 March 1971 17 March 1971 18-27 March 1971 28 March thru 5 April 1971 6-12 April 1971 13 April 1971 14-15 April 1971 16-17 April 1971 DRILLING FROM 20" CASING POINT TO 2700" Prill Float Collar and cement to Float Shoe. Pressure tested 40" OD Casing to 1000 psi for % hour. Drilled Float 'Shoe and drilled 17~" hole to 855'. Reduced hole size from 17~ ~ 12~" and drilled to 2700'. Mud: 9.5 ppg Vis 36 Deviation: 1-15' @ 850' . OPEN 12~" HOLE TO l?~" CONFIDENTIAL Open 12~" Hole to 17~" from 85~' to 2700'. Mud: 9.7 ppg Vis 75 W1 18,5 - Deviation: 02-30' @ 2700'. RUNNING 13 3/8" OD CASING AND CEMENTING Circulated to condition mud and hole for casing run. Run (66) joints of 13 3/8" OD, 68 & 61 #/ft, ½-55, Arctic Grade, Buttress Casing and landed at 2670' R½B. Mixed and pumped 3800 sx of 100% Fondu Cement. No cement return to surface. .Run l" OD XH Line pipe in 13 3/8" X 20" Annulus to 369'. Circulated mud out and mixed and pumped 470 sx of 100% Fondu Cement. Good cement returns (120) sx.- Landed 13 3/8" OD casing in 20" casing head. Pressure tested casing head seals to 1200 psi. InStalled 20"-2000 psi WP X 12"-3000 psi WP spool and 12"-3000 psi WP Double Ram and Annular Hvdraulic BOPE. DRILLING OUT OF 13 3/8" CASING Cleaned out cement from 13 3/8" OD ~casing and drilled out Float Collar. Pressure tested casing and BOPE to 1300 psi. Drilled out Float Shoe and hole to 2704'. Drilled on junk in 12~ hole below casing. (17~" Hole Opener Cutter) TEST BOPE Tested all the BOPE's and Choke Manifold with 3000 psi. Milled up junk in the hole and recivered small pieces of junk with Globe 8asker. DRILLING 12%" HOLE Drilled 12%" ~ole from 2709' to 4390'. Mud: 8.7 ppg Vis 36 Deviation: 04 ~5' ~ 43~0' - Tested BOPE's and Choke Manifold with 3000 psi Drilled 12%" Hole from 4390' to 5811'. Tested BOPE's and Choke Manifold with 3000 psi - Deviation: 03 15' @ 5778' Drilled 12~'! Hole from 5811 7706' - Tested BOPE's and. Choke Manifold - Deviation:' 5' @ 770G' - Mud: 9.7 ppg Vis 58 Wi 3.5 Circulated to condition hole and mud to log. LOGGING & SETTING PLUG ~ 7706' Run Schlumberger DIL Log. Set cement plug from 238G' to 2942' (580 sx Neat API G Cement). Tag cement piug ~ 238G'. Ciosed pipe rams and pressure tested cement piug with 500 psi surface pressure. SHUTTING DOWN FOR SUMMER Displace 13 3/8" casing with diesel oil. Lev down drill- pipe. Shut rig down. Stack~.equipment and materials fo~ summer shut down.. Rig release at 12:00 hours - April l'/, 1971 ½EMIM UNIT NO. 1 SUMMARY Page 2 17-22 Nov. 1971 23 NOV. 1971 24 NOv. thru 24 Dec. 1971 25-26 Dec. 1971 27-31 Dec! 1971 1-40an. 1972 5-10 Jan. 1972 ll-12_Oan. 1972 13-24 Oan. 1971 25 Jam. 1972 26-31 ,]an. 1972 RE-ENTERING HOLE Go in Hole with 12~" Bit. Stopped ~ 358't. Run 9 7/8" 8it to cement plug 9 2386'. Displace diesel with mud. Swage out 13 3/8" Casing from 357' to 360.'. Pressure Test 13 3/6" Casing with 500 -2000 psi for 20~ hrs. Casing leak after 6 hfs ~ 2000 psi. Drill cement with 12~" bit from 2386 to 2956. Mud: 9.8 ppg Vis 76 Clean out open hole below 13 3/8" Casing. Drill out bridges and circulate out sloughing shale. Operations partiallv shut down due to weather & lack of water for intermittant periods. ..CONFIDENTIAL Condition hole & mud for Lagging. Run Schlumberger Dipme'ter Survey, Sonic Lag, Density Log from 13 3/8" OD Casing Shoe 'to TD RUNNING & CEMENTING 9 5/8" OD CASING ~ 7711' Condition hole and mud to run Casing. Drill 12%" hole to 7711'. Run 9 5/8" OD Casing: (30) joints 47.00 lbs/ft. S95, Buttress; (158) joints, 47.00 lbs/ft NBO, Buttress, casing Total Length 7710.39'. Casing landed ~ 7708'. Casing equipped with Float Shoe, Float Collar, Self-fill Differential Collar, DV Stage Cementing Collar ~ 2787' & Casing Safetv joint ~ 1798'. Cement 9 5/8" OD Casing thru shoe with 1160 sx Class G Cement. Open DV Stage Cementing Collar. Mix & pump 150 sx Class G Cement. Close DV Stage Cementing Collar & pressure test @ 3000 psi for 30 Minutes. Install 12"-3000 X 10"-5000 Casing Spool. Install 10"-5000 Double Ram Hvdaulic BOPE w/Blind Rams & 5" D.P. Rams, 10"-5000 Annular Hydraulic BORE, 4X2"-5000 Choke ~ Mill Manifolds. W.O.C. PREPARE TO DRILL 8~" HOLE W.O.C. Complete installation of 4"X2"-5000 Choke & Hill Manifold. Test all BOPE to 5000 psi for ~ hour. Pick up BHA & go in hole. Drill cement & DV Collar from 2777' to 2788'. Drill cement plug from 7189' to bottom of Float Shoe & Cement ~ 7110'. Treat cement contaminated mud. DRILLING 8~" HOLE Dr~ll from 7710' to 8168'. Mud: 10.2 ppg Vis 110 - Deviation: 09-00' ~ 8168'. NO Drilling. .CONFID N[JA[, Drill 8~" Hole to 8622'. Deviation: 07045, ~ 8594' CORE NO. 1 Trip for Core Barrel. Cut 8 15/32 X 3~" Core from 8622' to 8679'. Recovered 57'. Drill 8~" Hole to 8825'. Circulatei.& condition hole & mud for DST. Mud: 10.7 ppg Vis 100 wl 4.4 - Deviation: 07°15' @ 8817'. KEMIK UNIT NO. 1 SUMMARY Page 1-2 Feb. 1972 3-18 Feb. 1972 19-29 Feb. 1972 1-15 March 1972 16-21 March 1972 22 March 1972 23-31 March 1972 1-11 April 1972 12-15 April 1972 16-30 April 1972 1-5 May 1972 6-19 May 1972 20-24 May 1972 25-26.Ma¥.: 1972 MEMI½ UNIT NO. 1 DST NO. 1 P.O.H. Run Drillstem Test Tools, 1900' of water cushion & set packer ® 862N'. Open tester & packer failed. Made hole conditioning trip. Run'Drillstem Test Tools w/(2) Packers for DST No. lA. Set packers~ 8633' & 8639'. Ran 2000' Water Cushion. Opened tester & packers failed. P.O.H. Go in hole & condition hole to drill ahead. DRILLING 8~" HOLE Drill to 9539'. Test BOPE to 5000 psi. Deviation: 09030, @ 9350'. Drill to 10,~063' Test BDPE ~o 5000 Dsi - Mud: 10.7 ppg Vis 63 W1 4. - ~eviation: 05 15' ~ 9798'. Drill to 10,800' - Deviation: 02045, @ 10,450'. 03-00 ' to 10,994'. Mud: 10.6 ppg Vis 83 W1 4.2 - Deviation: @ lC, 925. .o. ,CONFIDENTIAL Run 8 15/32 X 3~" Core Barrel. Core from 10,994'to 11,044'. Recover 50'. Drill to 12,080'. Mud: 10.7 ppg Vis 75 - Deviation: 03000, @ 11,889'. Drill to 13,050'. Condition Hole & Mud ~o Log. Mud: 10.8 ppg Vis 8N - Deviation: 05 45' @ 13,010' LOGGING P.O.H. Run Schlumberger Dual Induction Laterolog. Sonic- Gamma Ran, Density-Gamma Ray & continuous (4) Arm Dipmeter Logs. Trip to condition mud & hole. Run United Geophysical Corp. Velocity Surveys on Schlumberger Line. DRILLING 8~" HOLE Drill to 14,306'. Mud: 10.7 ppg Vis 67 Deviation: 02045, @ 14,306'. Drill to 14,707'. Test BOPE to 5000 psi. Drill to 16,073'. Mud:~ 10.7 Ppg Vis 90 - Deviation: 03000, @ 16,073'. Reached Total Drilled Depth this date. Prepare to Log. LOGGING @ 1G,073' TD Make Trip, circulate to condition mud & hole for logging. Run Schlumberger Dual Induction LaterolOg; (4) Arm Continuous Dipmeter Survey; Sonic-Gamma Ray; Density-Gamma Ray f~om 13,050' to T.D. OPEN HOLE DST ND. 2-~~i~-,h~,TIAi~ui~LFiU.f.i~.iIAL Circulate to condition hole & Mud for drillstem test. Run Lynes Inflatable Straddle Packers & Test Tool Assembly, with 2200' water cushion. Set Packers @ 8679' & 8719'. CondUct drillstem with Initial Flow, Initial Shut-in, Final .Flow & Final Shut-in periods, for 8~ hours. Unseat packers &<pull 'Test Tool-Assembly out of hale. Recovered 210' of slightly 9as cut mud 8' no other liquzds. Mud: 10.7 PPg Vis 70 SUMMARY Page 4 27-29 May' 1972 30-31 MmV 1972 30-31 MaV 1972 1-3 June 1972 4 Dune 1972 5-6 June 1972 7-90une 1972 KEMIK UNIT NO. 1 SET OPEN HOLE CEMENT PLUGS Measure open ended drillpipe in hole to 13,501'. Circulate ?o condition mud & hole. Mix & Pump 100 s× Class 6 Cement + 0.5% DBR Retarder. CIP ~ OlO0 hrs., 5-28-72. Pull up ~ole, measuring drillpipe to ll,lOl'. WOC 5 hrs. Mix & pump 100 sx Class G Cement + 0.5% DBR Retarder. CIP ~ 0900 ~ ~s. 5-28-72. Pull out of hole. .Measure open ended drtllpipe in hole to 9429'. Circulate to condition hole & mud. Mix & pump 150 sx class G Cement + 0.21% DBR Retarder. CIP ~ 0030 hrs., 5-29-72. Pull out of hole. WOC 8 hrs. G.I.H. with BHA to 7708'. Circulate & condition mud. ]6.I.H. & Tag Cement Plug ~ 9158'. Firm Cement. IJU'NI-ItII'N/I / Circulate to condition mud & hole. P.O.H. Run (42) jolnts of 7" OD, 29.00 lbs/ft., NB0, Buttress, Range 3 Casing (Liner); equipped with Shoe, Landing Collars, Liner Hangar & Tie Back Sleeve. Total Length 7" OD Casing 181D.34'. Top of Tie Back Sleeve ~ 7340.84'. Bottom of Liner ~ 9158.00'. Set Liner Hange~. Mix & Pump 50 sx Class G Hi-Vis Cement followed bV 500 sx Class ~ Cement + 0.10% DBR Retarder. CIP ~ 1030 hrs., 5-31-72 W.O.C. 24 hrs. COMPLETION PROCEDURES Continue W.O.C.. Tag top of Liner ~ 7339'. P.O.H. Pick up 6" Bit & 2 ?/B" EUE, NBO, 6.50 lbs/ft. Tubing & measure in hole.' Tag top of cement in 7" OD Liner ~ 8819'. Drill cement to 8863'. Circulate, treat cement contamination out of mud. Run Schlumberger CBL-Gamma Ray Log from 7100' to 8863'. Run Retrievable Packer & Set ~ 7330'. Pressure Test Liner to 2000 psi. Perforate interval 8780'-8800' with Schlumberger Casing Perforator loaded;.with~erjets per foot. Run Retrievable Packer Test Tools on 2 7/8 EUE Tubing, with 2000' water cushion for Hookwall Packer Test No. 1.. Set packer ~ 8745'. Open Test Tool. Bet immediate w~ak blow which died after 15 minutes. Close Test Tool for shut-in pressure. Unseat packer & POH. Water Cushion 15' high & mud cut. Test Tools plugged. Re-run same Test Tool Assembly for HookNall Packer Test No. lA. Set packer ~ 871~' Open Test Too~ get immediate blow for 8 minutes whic~ died. Leave Test Tool open 135 minutes. Get no further blow. Close Test Tool for Shut-in Pressure. Release packer & reset ~ 8681'. Open Test Tool for 85 minutes. No Blow. Release packer & POH. Found thick mud 15' above Test Tools. IHP 5022; IFP 4698; FFP 4779; FSI 5202; FHP 49N1 - Mud: 10.5 ppg Vis 100 W1 4.0 Circulate & condition mud. Treat out cement contamination. Run Retrievable Packer & Test Tools on 2 7/8 EUE Tubing with 2000' of Water Cushion for H._~okwall P~cker Test N°. lB. Set Packer @ 8703'. Open Test Tools for immediate s-~~ow. Tester Open 5 minutes for Initial Flow. Close Tester 127 minutes for Initial Shut-In PressUre. Open TeSter for Flow Period (1) for 266 minutes. 6as to surface in 2 minutes. Wate~ cushion to surface in 19 minutes. Flow thru Test Separater Orifice Meter Run. Open TeSter. for flow for minutes ~ ~ates of 2.05-2.14 MMCFD- 'TeSter for Final Sbut- In Pressure (2) for 165 minutes. Release packer '&.POH. Recovered 20' of apparent mud filtrate above Test Tools. Bottom Hole Flow Tube size 7/8". ONFt NTIAL 10 Oune 1972 11-12 3une 1972 13 Oune 1972 14 Dune 1972 15 Dune 1972 16 Oune 1972 17 Dune 1972 18-26 Oune 1972 n&rculate to condition mud. Run Schlumberger Casing Perforator, loaded with (&)-~" Hvperjets per foot & perforate interval 866N'-8780'. Hud: ll.2 pmg Vis 63 W1 Run Retrievable Packer & Test Tools with 2000' of water rushion for HoQkw~].l P~c~ Test No. 2. Set packer ~ 8:609'. Open Tester for initial Flow for 5 minuteS, for immediate trong blow. Close Teste~ for Initial Shut-In Pressure for _35 minutes. Gas to Surface in l0 minutes, (while Teste~ closed). Open Tester for Flow Reriod. Water Cushion to 'surface in 7 minutes. Flow for 360 minutes..~ ~ate of lO.14 MMCFD. Closs_~e_ster fd~ 'Fi'nal Shut-In Pressure for Open circuia~ t string & ~everse circuiate to stabiiize mud coiumn. Reiease Packer & POH. Circulate to condition mud. Mud: 11.1 ppg Vis 58 WI 6.0 Set Baker Model N Bridge Plugs 9 6596' & 8586' (wire line measurement) with Schlumberger wire line in 7" OD Liner. Tag top of Baker Bridge Plug ~ 8578'. In Hole wlth 2 7/8 EUE Tubing hung ~ 8578' in 7" OD Liner. Mix & pump 50 sx Class G.Cement + 0.2% DaR Retarder. CIP @ 0225 hrs. WOC 7~ hrs. Hang 2 7/8" EUE Tubing 9 7176' in 9 5/8" OD Casing. Mix & pump 100 sx Class G ~ment. CIP @ lll5 hrs. Hang tubing 9 6745', Mix 175 Bbls. ll.3 ppg mud & displace down tubing. POH. Set Baker Model N B~idge Plug ~ 2600'-in 9 5/8" OD Casing (wire iine measurements). Tag top of B~idge'Piug ~ 2587' with 2 ?/8" EUE Tubing. Hang 2 7/8" EUE Tubing ~ 2576'. Mix & pump 100 sx Class G Cement. CIP ~ 2400 hrs. POH. Remove BOPE. Run Casing Spear & engage 9 5/8" OD Casing @ G9~. Disconnect 9 5/8" OD Casing Safetv joint ~ 1798' RHB. Pull out &lav down (42) joints, 1781.8~' of 9 5/8" OD Casing. GIH with 2 27/8" EUE Tubing to 1800~in 13 3/8" Casing. Mix 150 Bbls. of ll.2 ppg mud & displace down tubings. POH. ' Mud Level standing ~ 55' RMB last 24 hou~so Tearing Rig Down. Bolt ~" Plate on 12"-3000 X 20"-2000 Casing Spool with 6" Hole cut in center; 13 3/8" OD X 6' Long Casing welded to plate with %" solid plate welded to top. Well Shut-In Complete. Tea~ Down B~tnke~hoff Rig No. 1. iCONFIDI Ni'I, AI. ½EMI½ UNIT NO. SUMMARy Page 6 Transmitted herewith are the following materials per- raining to the Forest Oil Corporation Kemik Unit No. 1 well Sec. 17, T1N, R20E UPM. Please acknowledge receipt by sign- ing and returning one copy to this office. ITEM NO. PIECES DEPTH MUD LOG DIL 2" Composit DIL 5" (Runs 1, 2 & 3) BHC Sonic 2" Runs 1, 2 & 3 BHC Sonic.5" Runs 1, 2 & 3 FDC Density 2" Runs 1 & 2 FDC Density 5" Runs 1 & 2 CBL Cement Bond Run 1 Caliper 4 Arm Dried Well Cuttings Core Chips Company: STATE OF ALASKA 1 Print 1 Sepia 1 Print 1 Sepia 3 Print 3 Sepia 3 Print 3 Sepia 3 Print 3 Sepia 2 Print 2 Sepia 2 Print 2 Sepia 1 Print ~ Sepia 1 Print 1 Sepia 1 Set 2 Cores 700 - 16,073 2,680 - 16,059 2,680 - 16,059 2,668 - 16,060 2,668 - 16,060 7,708 - 16,059 7,708 - 16,059 6,950 - 8,859 8,499 - 8,864 ~0- 16,073 CONF DF. NTiAL Received by: ...... Date o- Fo,-,~ No. ~,--4 STATE OF ALASKA B~'V. OIL AND GAS CONSERVATION COMMITi'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE 4. DCA~ON OF WF-J~L 2,073' FSL & 2,396' FEL - Sec.17 SE/4 Sec. 17 - T1N,R20E AP1 NUAiERICA_L CODE 50-223-20006 6. LEASE DESTGI~TA~'FION AXD SE1KIAL NO. Fairbanks 021270 1. ?. IF INDIA~T, ALOT iEJ~ OJq TRIBE NAME oil [] o~s ~ OTH~-~ Exploratory None WELL WELL 2. NA/~E OF OP~TOR 8. L~IT,F.~RA{ OR LEASE NAME FOREST OIL CORPORATION Kemik 3.ADDRESS OF OPElq. ATOR 9. WISL,L N'O. 425 "G" Street Suite 410 Anchorage,Alaska 99501 1 10. F!e:Lr~ A-ND POOL. OR WILDCAT Wi ldcat 11. SEC., T., R., 5~.. (BOTTOM HOL~ oB,mcu-n~ Sec.17-T1N, R20E Umiat Meridian 12. PIgRNIIT NO. 70-60 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA!~GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A/WI) VOLLrMES USED, PERFOI{ATIONS, TESTS A/xrD I~ESIJLTS. FISHING JO~S. JU/~K LN HOLE A_ND SIDE-/q{ACKED HOLE AND ANY OTHER SIGNIFICANT CI-IAJXT~E,S IN HOI.~ CON'DITIONS. ~ ~/. //~.~ c~~ i/~, : ,/~ ~oo"~. oe ~t/oo ~. c~,, "~ "~~, 11,1o o ~ ~ "l ~/i~' ~'~/'~" s~ ~.~..,. ( ~ , ~ :~= ~+s t.. supt./ ~,~ d- z~- 7~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. l~rm No. P--4 ~. s-~ STATE OF ALASKA suBMrr IN mn'L:CA~ ~. i~ ~mmc~ CO~E OIL AND GAS CONSERVATION CO~I~EE 50-223-20006 6. L~SE D~:GNA~ON AND~ MONTHLY REPORT OF DRILLING Fairbanks 021~ AND WORKOVER OPERATIONS 1. 7. IF INDIA~, A~T~E OR °'~ ~ ~*' ~ 0~.z, Explorato~ none ~. N~E 'OF OP~TOR ' 8. L~IT F.~i OR LEASE FOIST OIL CO~O~TION KoOk 425 "G" Street Suite 990 ~chorage, Alaska 1 2,073' FSL & 2,396' FEn Wildcat SE 1/4 Sec 17 T1N, R20E "n. ssc..=..~..~,..(~.~6~ · o Umiat Meridian 1~. P~IT NO. 70-60 ,,, , 13. REPORT TOTAL' DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND CEAiENTING JOBS INCLUDING DEPTH SET A-N-D VOLI/NIES USED, PEP~FOI{ATIONS. TESTS A/~qD I~ESULTS, FISHING JOB~, JLrNK IN HOLE A-ND SIDE-TIq~CIf~ED HOLE AND ANY OTHER SIGNIFICANT CIiANGF~S rN HOL~ CON'DITIOI~S. CONFIDENTIAL _ . / / , NOTE--Report on this form is required for each calendar month, regardless of the s of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Mr. Rodney Smi%h Regional Oil & Ga~ Supervisor Branch of Oil & Gas Operations U.S. Geological Survey P.O. Box 259 Anchorage, Alaska 99501 Anchorage May 1, 1972 DIVISION OF OIL .~,N::~ .:' '? ANCHO '"': Re: Kemik No. 1 Forest Oil Corp' Dear Mr. Smith: The purpose of this letter is to supplement our letter of November 24, 1970, outlining our operational plans for the drilling of the subject well. The'decision to drill below the- original target depth without shutdown required changes in operational procedures which are outlined below. A. LOCATION - Information given below describes work to be performed in addition to that of our original operational plan. 1. Drillsite Area. The area surrounding the drilling .rig and its related equipment is being graveled. The area (300' x 700'+) will provide work and storage areas for rig support work. 2. Rig Camp.. This camp is located 400'+ from the well. The area immediately adjac- ent to portions of the camp will be gravel- ed to provide access from the drillsite area. 3. Reserve Pit. The berms surrounding the origin~'l reserve pit are to be enlarged and strengthened with gravel. A second reserve pit, in the form of a trench' (30'x 400'+) has been excavated downgrade from the original pit to contain possible overflow and leakage. 4. Fuel Storage. The fuel storage area will be' enlarged with additional gravel berms. CONFIDENTIAL Mr. Rodney Smith U.S. Geoloc~ical Survey Page 2 B. AIR STRIP - A gravel airstrip (60' wide x 1800' long) is being constructed for use after breakup. The gravel airstrip will accommodate Twin Otter type aircraft and will be connected to the gravel location area by a gravel road. C. MATERIAL & EQUIPMENT MOBILIZATION. 1. Fuel is being stockpiled at the location. 2. Mud'materials are being stockpiled at the location. · · Access has been granted us by McCullouch Oil Corp. to the Herc Strip at Fin Creek. Should additional materials or equipment be required which cannot be brought into the Kemik air strip, they will be brought into the Fin Creek strip and transported to Kemik on Rolligons. Water will be pumped from nearby creeks and rivers. Additionally, Rolligons will haul water from lake sources. The plans and procedures outlined above have been coordinated with the Fairbanks District Office of the Bureau of Land Management. Contact will be maintained with your office and the BLM in Fair- banks during the remainder of our operational period. I trust this summarizes our plans satisfactorily. Sincerely, FOREST OIL CORPORATION H. E. Snider Division Production Manager HES/p ILEV. 9-30-69 & "Sut:mequent Reports" in Duplicate STATE OF ALASKA 5. APZ ~T~¢~. ¢,~DEj 2 E~ J OIL AND GAS CONSERVATION CO~I~EE. 50-22]-200a SUNNY NOTI~S AND R~O. RTS ~ W~ Fatrbank~ ~ "~,c-~oN'~0~~=~' ~o~.~u~h'~'~ 021270 OIL ~JL~ ~ GAS -,~ ~ o~,, Exploratory N/A I ~ ~ ~" FOREST DIL CaRPaRATIO~ ~m~ 3. ADD2~SS OF OP~ATOB 9. ~L NO, Suite 99D-~25 "G" Street~ Anchorage~ Alaska 99501 1 4. ~OC&T~O~ O~ W~ 10. ~ ~ ~; O~ WT;.~~ . 207) ~ FSL 2)9G ~ FEL ~. s;c** ~., ~., ~** ~o~ ~o~ O~I~) SEA Sec 17 TiN R20E SE~ Sec i? TIN R20E UPM Umia~ P~inclpal Me;idian ~3. ~VA~IO~S (Show wbetbe; D~, R~, OR, etc. 12. ~ ~O. Ground 1220 RKB 1234 ?0-60 Check Appropriate Box To I,ndicate N;ature of I~ti'ce, Re zort, or Other Data ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ] I PULL OR ALTER CASING FRACTURE TREAT -- MULTIPLE COMPI.ETE SHOOT OR ACIDIZE -- ABANDONs REPAIR WELL CHANOE PLANS ~Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEN'T* (Other) (NOTE: Report results of multiple completion on Well Completion or Rec0mpletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. · The follouin9 is to supplement our SUNDRY NOTICE of 19 April 1972 KvakShale l",OOO Oevonian 15,25'0 MAY PROPOSED CASING (Liner) PROGRAM Depths Size Weight Grade 7500-7900 7" OD 29.00 lbs/ft NBa 7900-12~900 7" OD 29.00 lbs/ft Pl10 12,900-16~500 7" OD 32.00 lbs/ft Pll0 Thread Buttress Buttress 8utteess PROPOSED LINER CE~NTING Cement Liner thru Shoe from 16,500 to 13,500 uith 600 Sx Class G Cement CONFIDENTIAL 16. I hereby certify th~ the foregoi~ is true ~d correct (This space for State office u~,j7 .~ . CONDITZONS OF ~,Pi~Rb%,~L, IF AN~: ~ ' T~TL~ See Instructions On Reverse Side Approved CoPy Returned .._.~- ~ -7 z_ Form REV. 9-30-6 9 S~brntt "Intentions" in Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FoR/~i~RlgiiT-L' 'for such'pi;o~osal~.) . o... ~ G., Exploratory W£LL WELL [] OTHER 2, NAME OF OPERATOR Forest Oil Corporation 3. ADDRESS OF OPERATOR 425 "G" Street Suite 990 An. chorage, Alaska 4. LOCATION OF WF-~L At surface2, 0 73 ' FSL 2,396 ' SE 1/4 Sec. 17 T1N FEL R20E 13. ELEVATIONS (Show whether DF~RT, OR, etc. Ground 1,220 K....B. lr234 14. Check Appropriate Box To I,ndkate Niature of" N~ofi'ce, Re - ! ..... !", 5. AP1 NI/N~CAL CODE 50-223-20006 :~ ,.-~ Fairbaks 021270j I ~:'~' ~. IF I~I~, ~~ OR TRIBE none i _ _ ~ _i ' -~ ......... 8, UNI% F~ OR ~SE N~IE i~k 1 ~ ,,, Wi 1.dc at 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 17 T1N, .R20E Umiat Meridian 12. PERlVI~T 1~O. 70-60 ,, ~.. or Other D~t~ ' NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLAN8 -- tOther~ SUBSEQUENT REPORT 0l~ : WATER SHUT-OFF __~~ REPAIRINO WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ~ ABANDONMEIqTs (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletlon Report and Log form.) I5, DESCRIBE PROPOSED OR COMPLETED OP~.RATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We request .permission to continue 'drilling operation on the above deS'cribed well to. the .Devonian f'o'rmation at approximately 14,500' feet and .to a total depth 'of approximately 16,000' feet. APR 2 i 1§7 CONFIDENTIAL 16. I hereby certffy~{ha/th_iL foregotn~tt truB ani~/coFee~ szo~ LE Produc~_Jon DSvision ...... ~--.~ ~ CONDITIONS OF~AP~b~ iF AN~: ' DAT~ 4/19/72 DATE See InstructiOns On Reverse Side Approved Copy Returned l~orm No. P---4 REV. 9-30-~7 ( STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. ~LL 2. NA.ME OF OPgI%ATOR 3. ADDRESS OF OPEH. ATOR SUBMIT IN DUPLICATE AP1 NU~.iER1CAL CODE 6. LEASE DE.SiG1~A%~ION AND SEI~IAL NO. 7. IF INDIA]~T, ALOTIEE OR TRIBE NAI~IE 8. I~.~IT,F.~.I~{ OR LEASE NA~ME 9. wELL NO. ! 10. t'~l.lfO-,D ~_NID POOL. O~ WI~DC~W I1. SEC.. T., R., M., (~OM HO~ o~ 70-60 13. REPORT TOTAL DEPTH AT END OF MONTI-I,CI-L~qGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AJ~D VOLLflvrEs USED, PEP~ORATIONS,TESTS A_N'D RESULTS, FISHING JOB~, JUNK IN HOLE AND SIDE-T~ACKED HOLE AND ANY OTHER SIGNIFICANT CHA_NGF~ IN HOL~ CONDITIONS. CONFIDENTIAL 14. I hereby ce~t the f~egoing is true and correct NOTE~Report on this form is required for each calendar month, regardless of the status of operations, and must ~ filed in duplicate with the Division of Mines & Minerals by the lSth of the succeeding month, unless otherwise directed. F~rm No. 1:'--4 STATE OF ALA~ SUBMIT LN DUPLICATE OIL AND GAS CONSERVATION CO/V~ITTEE API NU~IERICAJ~ CODE 50-223-20006 6.LEASE DESiGI~TA ~ION AXD SEq~IAL NO. MONTHLY REPORT OF DRILLING Fairbanks 021270 AND WORKOVER OPERATIONS 1. T. IF INDIA~, ALOTTEE O~ TRIBE NA~E 0~L ~ o~, ~ OT.Z. E~lorato~ none ~ELL ~ELL 2. N~E OF OP~TOR 8. %~IT,F.~{ OR LEASE Forest Oil Co~oration Kemik 3. ADbRESS OF OPhiR 9. %VE~ 425 "G" Street Suite 990 ~chorage, Alaska 1 4. LOCATION OF WFJ~L 10. ~'~ ~-ND POOL, OR WILDCAT 2,073' FSL & 2,396' FEL . Wildcat SE 1/4 Sec 17 T1N, R20E n. SEC..T..R..*~..mOm'OMHOLE Sec. 17 TIN, R20~. Umi at Me ri di an 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CI~A~GES IN HOLE SIZE, CASING AIN-D CE~IENTING JOBS INCLUDING DEPTH SET AND VOLLrNIES USED, PERFOI{ATIONS, TESTS A/XFD I~ESULTS. FISHING JOBS, JLrNK LN HOLE /~ND SIDE-TRACKED HOLE AND A,NY OT~EER SIGNIFICANT CH_AJXTGE~ IN HOI~ CONDITIONS. MAR ~, 197~ OIVISlON O!~ OIL AHb ~A{ CONFER: FILE: CONFIDENTIAL 14. I hereby cert~ the Eoreg~g is true and corrent ~,~ .,.'-.'-.: C. ,,~.,_:L/~ ,.,.,= ,~.,_:,,.~. ,,%/~. ~. ~,,.,., _.--'- ./-- zz, NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. l. ox-m :No. P--4 REV. STATE 0~~ ALASKA SUBMIT IN DLq::'LICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o,L [] ,~,,,, [-j o,~, Exploratory WKLL WELL 2. NAME OF OPERATOR Forest Oil Corporation 3.ADDRESS OF OPEI~ATOR 425 "G" Street Suite 990 gnchorage, Alaska LOCATION OF WRTJI~ 2,073' FSL & 2,396' FEL SE 1/4 Sec. 17 T1N, R20E 8. L~'IT,F.~{ OR LEASE N.A/~E Kemik 9. WELL .N'O. 1 10. FTI~.T.r) AND POOL. OR WILDC.~ Wildcat 'i1. SEC., T., R., 5{., (BO/~OR{ HUh OBJECrr~E) Sec. 17 T1N, R20E Umi at Me ri di an 12. PERMIT 1~0. 70-60 13. REPORT TOTAL DEPTH AT END OF MONTH, CPL~N'GF.S IN HOLE SIZE, CASING A/%rD CEA~ENTING JOBS INCLUDING DEPTH SET ~ VOLU~IES USED, PERFOI{ATIONS, TESTS A/ND RESULTS, FISHING JOBS, JUNK IN HOLE A_ND SIDE-TRACKED HOLE A. NT) AJqY OTHER SIGNIFICANT CI-LA/~ES IN HOL~ CONDITIONS. o/ FEB 9 197 DIVIS,iON OF O!L AND¢'~ ~ ~4CHC':~ ,. ~ CONFIDENTIAL 14' I hereby~rtify ~~----~°~u~an~l ~/~2 ~ ~) ~//' 7/ NOTE--Report on this form is required for each calendar month, regardless of the s~us of operations, aha must be filed in duplicate with the Division of Mines & Minerals by the 1Sth of the succeeding month, unless otherwise directed. REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT LN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o,L [] G,, [] oT~. Exploratory WELL WELL 2. NAME OF OP~TOR ~O~ST OI~ CO.OPTION 3. ADDR~S OF OPhiR 425 "G~ Stroot Suite 990 ~chorago, ~laska 4. LOCA/~ON OF WELL 2,073' FSL & 2,396' FEL SE 1/4 Sec. 17 T1N, R20E AP1 NUAfERICA~L CODE 50-223-20006 6. LEASE DESIGNATION AXD SERIAL NO. Fairbanks 021270 7. IF INDIAN, ALOI fEE OR TRIBE NAME none 8.L.~IT,F.~ OR LEASE NAA~E Kemik 9. W~L.L NO. 1 10. FIELD A-ND POOL, OR WILDCAT _ Wi ldcat 11. SEC., T., R., M.. (BO/~'OM HOLE OBa~TnrF~ Sec. 17 T1N, R20E Umiat Meridian 12. PER/VIIT lXTO. 70-60 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~GES IN HOLE SIZE, CASING A/~D CEMENTING JOBS INCLUDING DEPTH SET b~NI) VOLUATE~ USED, PERFORATIONS, TESTS A/xrD I~ESULTS, FISHING JOBS, JLTNK IN HOLE A_ND SIDE-TTLACKED HOLE AND ANY OTI{ER SIGNIFICANT CI-IA~GF~ IN HOL,~ CONT)ITIONS. CONFIDENTIAL 14. I hereby ~t ee the ~regoing ~ true and correct , NOTE--Report on this form is required for each calendar month, regardless of the status of operations, ancl must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form I~_EV. 9-30~ 9 STATE OF ALASKA Smbmtt "Intentions" in Triplicate & "Sub.~quent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR/~"ER~iT--;' 'for such 'pl:o~osal$.) _ , Gl,. ~ ~.xpl WELL ~ o,s oratory WELL OTHEE 2. NAME OF OPERATOR FOREST OIL CORPOI:~TION 3.ADDRESS OF OPERATOR 425 "G" Street Suite 990 Anchorage, Alaska 4. LOCATION OF WELL At surface 2,073' PSL 2,396'FEL SE 1/4 Sec. 17 TiN, R20E ,, 5. API NUNIERICAL CODE 50-223-20006 61 LE'A~E DESIGNATION A_ND SERIAL NO. Fairbanks 021270 7. IF INDIAN, .~J~I.O'I"I~ OR TRIBE NAIVI.E none 8. UNIT, FA_R/VI OR LEASE NAME Kemik 9. WELL NO. 1 10. FIEIJ~ AArl) POOL, OR WILDCAT Wildcat 11. SEC., T., R., M,, (BOTTOM HO/.2~ OBJECTIVE) Sec. 17 TiN, R20E Umiat Meridian 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PERIVIIT NO. Ground 1,220 K.B. 1,234 I 70-60 14. Check Appropriate Box To I,ndi,cate N, ature of N~ti'ce, Report, or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~--~ PULL OR ALTER CASINQ EUBSEQUENT REPORT OF: REPAIRINO WELL ALTERING CASING FRACTURE TREAT __ MULTIPLE COMPI,ETE FRACTURE TREATMENT SHOOT OR ACIDIZE ~ ABANDONs SHOOTING /ABANDONMEN'T$ REPAIR WELL CHANGE PLANS (Other) . ' ~al~'J'~'i,~_~. (Other) -- (NOT~: Report results ~f multiple complan on Well _ Completion or Recompletion Report and Log form.) 15. v~:sc~ns PnOPOSSD 0~ COMPLETED 0PERATION8 (Clearly s~ate all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. CONFIDENTIAL (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side · Form P--:~ REV. 9-30~ 9 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Smbrnit "Intentions" in Triplicate ~ ~" & "Subsequent l~ports" in Duplicate SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form /or proposals to drill or to deepen Use "APP-LICATION 'FOR ~'EF~I']]'-L~' 'for such 'p~o~osal$.) . oil ~ oas ~ Exploratory WiLL ~ ./ WELL OTHER 2. NA~IE OF OPERATOR Forest Oil Corporation 3. ADDRESS OF OPERATOR 425 "G" Street Suite 990 Anchorage, ~aska 4. LOCATION OF WELL At surface 2,073' FSL 2,396' FEL SE 1/4 Sec. 17 T1N, R20E 13. ELEVATIONS (Show whether DF, RT, GH, etc. Ground 1,220 K.B. lr234 14. Check Appropriate Box To Indi'cate Nature of N~tice, Re 5. API NI3/VIF_A~CAL CODE 50-223-20006 6. LF_J%sE DESIGNATION A_ND SERIAJ~ NO. Fairbanks 021270 7. IF INDIAN, ALLOTTEE OR TRIBE NA/V~ n one 8. UNIT, FA/~NI OR LEA~E NA~ME Kemik WELL NO. 1 ~o. Fm-~ A~ ~OOL, o~ w~u~CAT Wi ldcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 17 T1N, R20E Umiat Meridian 12. PER/W/T NO. · 70-60 ~t, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACID~ZE ABANDONS REPAIR WELL CHANGE PLANS tOther) .... SUBSEQUENT REPORT OF: WATER SItUT-0FF REPAIRIN~ WELL FRACTURE TREATMENT ----- ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEKT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. NOV DIVISION OF OIL AND CONFIDENTIAL (This space for Stat!offic9 u~)// See Instructions On Reverse Side Approved Copy Returned , REV. 9-30~9 & "Subsequent Reports" in Duplicate ,,% STATE OF ALASKA 5" ..,,.m NmVl.r~c.a., CODE J I .':,",'C " F-NGI OIL AND GAS CONSERVATION COMMII'I'EE ¢, <.. r x '\i ~'' - '¥ 50-~-23-20006 SUNDRY NO?ICES. AND REPORTS ON W~l~ .. '~z:~- ~' ~airbanks 02127 (Do not. use this iorrn for proposnls to drill or to deepen ' J j ........... '. C~ .5 ENG use "A~P-btCATION. . ~O~ PE_~/H'i'--" for $~eh'p~:o~o~at$.) ~'..-', :,J .. ~) o,L ~ ~AS ~ OT.,R Wildcat l ~nL ' ~ wE~5 none ._ '~'i NAME OF OPERATOR 8. UNIT~FAR-1VI OR L,F. JkSE NAME J ~ L~%)[_ J FOREST OIL CORPORATION Kemik --J ..... REV J ~. ^gDr~SS OF OrEr~TOS S. W~L NO. ! DR^Ff J -- 425 "G" St. Suite 990 ~chorage, Alaska 1 -4. LOCATION OF WEJ~L 10. F/.F_J.J) A2/D POOL, OR WILDC At ,,~¢~ 2,0 7 3' FSL 2,39 6' FEL SE 1/4 Wildcat ~!L~: Sec 17 TIN R20E u. sec.. T.. R.. M.. (SOVrO~ · OBJECTIVE) Umiat Meridian Sec. 17 TIN R20E Umiat Meridian .... 1R I~.I.I~VA'FIC)N~R (.~hr~z wh~t.h~r DI~. RT. ~H. etc. 12. PERMIT 1~O. Check Appropriate Box To I;nc~icate N, ature of N~tice, Re tort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE J J ABANDONs REPAIR WELL CHANGE PLANS 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent proposed work. 5 o t (Other) -- ~ ~ (NOTE: Report reaulta of multiple completion on Well Completion or Recompletion Report and Log form,) details, and -tve pertinent dates, tneludin~ eetimated data of starting any 16. I hereby certify,~t the for,~oln$ is true and correct SIGNED , APPROVED BY '~,o ,,- -~, " CONDITIONS Old'APPROVAL, IF ANY: TITLE TITLE See Instructions On Reverse Side DATE /'[/~/~/,, , Approved C~py ~eturned Form P--3 S~brntt I~LEV. 9-30-6 9 STATE OF A~KA J-'l ENG' OIL AND GAS CONSERVATIO'N CO~I~EE ' ,j-2 ENG-~ 50-22]~zag~ ' . ' J 3 ENO ~ PlYISIDN OF Oil AND GAS (~ not use t~Js Jo~ Jo~ p~oposaJs ~ ~l'Jll o~ to ~eepe ........ ~_ Fan,bank us~ "X~CA~ZO~'~O~ ~rr~" ~o~ ~'p~o~a~.) J 5 ENO J .... ~,~ ~ ~,~ ~ o~.,. ExploratorV J~ G~OL j~b None 2. NAME OF OPE~TOR J 3 GEOL J~ ~. UNIT, F~ OR ~SE N~E ..... FD~EST 0IL CD~PD~TION. ~. ~ss o~ o~o~ ~ D~A~_ ~. ~= ~o. &25 "S" Street - Suite ~lS~ ~nchora~e; ~i8~s~5~ 1 4. LOCATION OF %V~L CON~: 10. FIELD ~D P~L, OR WI~CAT at su,'~ace FILE: Wi 1 dca .... ll. SEC., T., R., ~., (BOT~ ~O~ 2,073' FSL & 2,396' FEL - Se~. 17 o~v~ SE/4 Sec. 17- T1N, R20E Sec. 17- T1N, R205 Umiat Ms~idian "'~. ELEVATIONS (Show whether DF. ~T. GE, etc. l~. PE~T ~O. 170-60 I 14. Check Appropriate Box To In. dicate N, ature of N~ti'ce, Report, or Other Da~a ' NOTICE OF INTENTION TO: J ImUBeEQUENT REPORT OF: 8HOOT OR ACIDIZE ABANDON* 8HOOTING OR ACIDIZING ABANDONMENT· REP*lB W~LL CHANg, PLA~S J__ J (Other)Temporary Suspension , ~otber) ~ __ (~o~m: ~epo~t ~e~ult~ of muldple completion o~ Well , ~ompletton o~ ~eeompletlon ~epo~t ~=~ ~o~ fo~m.) I5. DESCRIBE PROPOSED OR CO.MPLZTED OPERATION8 (Clearly state all perttneut details, and give pertinent dates, including estimated date of starting any proposed work. ~p~!~. 20, 1971: Drilled 12~" to 7,706'. Ran D-I Laterlog to total, depth. Set 580SX ce'me~{-plug - 250' in~and 250' below 13 3/8" casing. Tagged cement plug 2,386' and tested w/500 psi - held 0.~, Displaced 13 3/8" casing w/diesel fuel~ Laid down remainder of drillpipe. Olosed blind rams on BOPE and installed pressure gage. on same. Prepared all surface facilities, including airstrip, for temporary suspension. All suspension operations and personnel off location (including airstrip) 1:00 pm., 4-19-71 CONFIDENTIAL CONFIDENTIAL 16. I hereby certif at the foreg~g is true and correct SIGNED ~h~%,.i . A '~;/~/~~ITLE District Division Supt, (This space for State office use) DATE 4-21-7~, APPROVED BY CONDITIONS OF APPROVAL, IF AN~: TITLE DATE See Instructions On Reverse Side REV. 9-30-69 & "Subsequent Reports" /n Duplicate STATE O'F ALASKA ~. API Nmm~UCAL OIL AND GAS CONSERVATION CO~I~EE 50-223-20006 SUNNY NOTICES AND REPORTS ON WE~ (~ not use this fo~ for proposals ~ drill or to deepen Fairbanks 02127~ ~. ~. ~r ~I~. ~o~ o~ rR~ '~i0~ 0,~ ~ ~,, E~lorato~ None ~ ~. ~AME O~ OPEBTOR 8. UNIT F~ OR 425 "G" St. Suite 410 ~chorage,Alaska 99501 1 A~ surface Wi ldcat CONFER: 2,073' FSL & 2,396' FEL - Sec 17 ~ O~E~IVE) SE/4 Sec. 17 - T1N,R20E Sec.17- T1N,R2~ ~at Meridian '~:~ ELEVATIONS (Shaw whethe~ DF. RT'. GE. e%c. [~. P~T ~O. I 7060 i 14. Check Appropriate I~x To Indi,cate N;ature of NOtice, Report, or Other Dat~ ' NOTICE OF INTENTION TO: TEST WATER 8HUT-0FF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS ,Other) Temporarily,, Suspend IIUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEN'T$ (Other), (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Proposed plans' for t'emporary .suspensi'on of operations: Permission requested to. eXeCute the o.perations listed below to permit temporary suspension 'of ope'rati:ons: until freeze- up in Fall 'of 1971.' 1. Run Schlumberger Log from .2700 to T.D. 2. Increase Mud Density to 10 5~ ppg 3. Place cement plug from 2400 to 2900' 4. Displace mud with diesel fuel 'from 2400' to 0' 5. Close in BOPE with pressure, guage installed 6. Shut down all support facilities and operations TITLE Div. Prod. Mgr. D-~,TE 4/5/71.. , (This space for State office ]~s,~)~ , CONDITIONS OF ~ppRbv~AL, IFA See Instructions On Reverse · _tc-..' 'EOL ~o~ go, P-~ STATE OF ALASKA SUBM~' m ~c~ , . I C. EN~....~ O~L AND.GAS CONSERVATION CO~I~EE 50-223-2000G J 2 EN'G .......... ' ' ~."~s[ D~O~A~ON ~X'~ S~ ~O~' EN~' MONTHLY REPORT OF DRILLING. Fairbanks 02127a-' J ~ ~'j AND WORKOVER OPERATIONS ....... ' °'~ ~ ~" ~ o~=. Exploratory None - ~0~ 0~ CO~O~ZO~ ~em~k i i i i 'a. ~a~ss or oP~m~ ~. w~ ~o. 425 "G" St. 8UitO 4~O'~chora~o,~laska ~501 1 ,,,~ ~ Wi ldcat FILE:. , , 2,073' FSL & 2,396' FEL- Sec. 17 [~p~.~r~. .~ ,-~ 7%/.¢, ] ,,.szc..t..,..,,..(~o,,.OU;o~ ' SE/4 Sec, 17 - T1N, R20~ Sec. 17 - T1N,R20E u,¥~ ...... .N C~:. c.f.. ,z,',:~ OAS Umiat Meridian , i 1 i i i i 70-60 . Il II II I REPORT TOTAL DEi~I'H AT END OF MONTH, CI-[ANGES IN HOLE SIZE. CASING AD~D CEMENTING JOBS INCLUDING D~ SET ~ VOL~ US~, P~O~TIO~S, ~TS ~ ~SUL~. ~O JO~. J~K ~ HO~ ~D 81DE-~C~ HO~ ~ ~ O~ SIGNIFI~ ~~ ~ HO~ ~ITIONS, ' Zo" 14 I he.by ~ify~ the forego~g ~ ~e ~ ~ ~ with t~ Division ~ MtMI I Mt~PItI by the 1~ ~ t~ succeeding ~flth, ufltlll , ,. , Form No. P--4 REV. 9-39-6V STATE OF A.I.A~KA OIL AND GAS CONSERVATION CON~II-i'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~z,.,. [] G,,~,.~ [] 0=.z, Exploratory NA/~E OF OPERATOR FOREST OIL COI:~O~TION 3. ADDRESS OF OPEllATOR 425 "G" Street suite 410 J~mch'orage, 4. LOCATION OF WF-J.,L 2,396' FEL & 2,073' FSL- SEC. 17 SE 1/4 Sec. 17 - T1N-R20E SUBMIT L~ DUPLICATE Alaska 99501 AP1 NLr~.~ERICAL CODE 50-223-20006 6. LEASE DESIGNATION AND SERIAL NO. Fairbanks 021270 7. IF INDIAAT, ALOTTEE OR TRIBE NAME none 8.L.~IT,FA~RA{ OR LEASE N.~E KEMIK UNIT 9. %VELL NO. ] 10. FIF_J.,D A_ND POOL. OR WILDC.kT Wi 1 do. at n. SEC.. T., a, M.. (SOT'rOM HO= o~ Sec. 17-TiN-R20E Umiat Meridian 12. PERMIT NO. 70-60 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA2qGES IN HOLE SIZE, CASING AND CE1ViENTING JOBSINCLUDING DEPTH SET A/XrD VOLI/MES USED, PERFORATIONS. TESTS A/XUD I~ESULTS. FISHING JOB~, JU/~K IN HOLE A_ND SIDE-/qlACKED HOLE A-~D ANY OTHER SIGNIFICANT CI-I.A~GES IN HOI~ CONDITIONS. February 28, 1'9'71: Drilling @ 1,497' w/12 1/4" bit. 'Drilled 36" hOle to 74' (K.B.). Set 30" conductor pipe @ 74' w/204 sacks of fondue cement. Drilled from under conductor pipe (Spudded)' @10:15 a.m., 2-14-71. Drilled and reamed to 26" to 694' (K.B.). Ran 17-jts.-691' (Net)-20"O.D. 133#, K-55, R-3, Buttress thd., New. USS, Casing Set @ 690' (K.B.) Cemented w/lt470 sacks of fondue icement. Good cement :returns. Job complete @3:20 a.m., 2-21'71. :Cut o'ff 20" O.D. casing and nippled up 20"-2000%W.P. casing head and Hydril. Pressure tested casing before drilling flOat collar w/1000 psi-held o.k. Begin 'drilling float collar @3:30 a.m., 2/23/71. 14. I hereby SIGNED is true and correct NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. I{EV. 9-3~-69 & "Subsequent Reports" in Duplicate · STATE OF Ai_ASKA 5. Am NmvmmcAL COD~. OIL AND GAS CONSERVATION CO~I~EE 50-223-20006 6. ~ D~GNA~ON ~D SK ~I~ ~UN~Y NOTIgES AND REPORTS ~ W~ (~ ~o, ..~ ~ ~o~ ~o~ .~opo~ ~ .,-.~ o~ ,o ,~,.~.~ Fairbanks 02~2:10 Use "~L~CAT~ON. '~O~ 9~rr~" tot suc~ o,~ ~ ~,. Explorato~ none W~LL ~ WELL ~ OTHER FOIST O~L CO.OPTION KE~IK 425 "G" Street suite 410 ~chOrage,Alaska 99501 1 ~ ~u,.~ Wildcat 2,396' FEL & 2,073' FSL- Sec. 17 ll. SEO.,T.,R.,M.,(BO~M~~o~E~iVE) SE 1/4 Sec.17 - T1N-R20E Sec.17-T1N-R26E Umiat Meridian 13, ELEVATIONS (Show whether DF. RT. GE, etc. 12. P~T NO. GR El'ev- 1,220' ; K.B. El.ev- 1.,234' 70-60 ,4. Check Appropriate Box To I,n:c[i'~ Nature of N~ti'ce, Re ~or~, or Other Data ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ]__[ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE I [ ABANDONS REPAIR WELL ] ~ CHANGE PLANS iOther) SUBSEQUENT REPORT OF: WATER 8IIUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ~ ABANDONMENT'# (Other) Move. Location (No~: Report ~e~ult~ of multtpl~ completion on Well Completion or Reeompletlon Report ~nd Lo~ form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The above described well was moved 'from the proposed site as submitted on the 'original "Application for permit to' 'Drill", due to the terrain of the 'ground. Attached please find the .actual location plat which shows the re-survey. C Hi:II ENTIAL pl¥tS,tON CF C;L ~,'~'~D GAS A~.~CH~aAG~ 16. I hereby eertffy/tJ~t the for~egoing is true and correct (This space for State office use) APPROVED BI' CONDITIONS OF APPROVAL, IF ANX: TITLE Dist, 'Prod, :Supt. TITLE See Instructions On Reverse Side DATE ,,2/22/71 DATE ~Appr°ved Co,p), ' ~eturned ~ _- ,,~,~ R. 20 E, ! I I 6 I 5 I 4 I I 1 I I 1 ? I 8 I 9 I I I I I I I I I 30 I I I I 2596' ~I ' I I Lot. 69026' I ___ I Long_:_.147° 16' 11.79" .... T- ry: 5,646,421~ I I X = 336,659I I I ELEV. MSL I 20 I MAT 1220' I I I I I I I I I 4 t 1 I I I I I I l 29 I I 15 22 27 23 26 24 25 CERTIFICATE OF SURVEYOR SCALE: I"= IMILE I hereby certify that i am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that oll dimensions and other details are correct. Date SURVEYOR TIN. REVISED LOCATION 2-17-71 ALL. KEMIK NO. I Located in of Protracted Sec. Surveyed for FOREST 0IL CORP. Surveyed by E M. LINDSEY 8~ ASSOC. LAND 8~ HYDROGRAPHIC SURVEYORS ;>502 West Northern Lights Bouleverd Box 4-081 Anchorage Alaska ~Jrln No. P---4 CONFIDENTIAL STATE OF ALASKA sun~rr u~ ~U~LZC~ OIL AND GAS CONSERVATION COMMITTEE J%~ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WZLL ~ W£LL 2. NA~ME OF O?F-2:LATOR ~ OT.Z~ Exploratory Forest Oil Corporation 3, ADDi{ESS OF ODEt~TOR 425 "G" Street Suite 410, Anchorage tAlaska 99501 4. LOCATION OF WFJ~I. 1900' Fel 1800' FSL SE 1/4 Sec. 17 T1N, R20E Umiat Meridian 5, APl NU.MEIIlCAL ('()DE No. 50-223-20006 6 LEASE DES[GBIATION AND SERIAL NO. Kemik Unit Fairbanks - 021270 7. IF INDiAIq', ALOTTEE OR TRIBE NANIE none 8. IaLNIT,FAR~! OR LEASE NAIVE Kemik 9. %VELL NO 1 10. FIELD A_ND POOL. OR WILDCAT Wildcat ~ 11. SEC.. T., t{.., M.. (BOTTOM HOL~ OBJF_~TIVE) Sec. 17 T1N R20E U.M. 12. PI~q. MIT iN'O. ' 70-60 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND C~%4ENTING JOBS INCLUDING DEPTH SET AND VOLUM-ES USED. PEH~ORATIONS, TESTS A2CD RESULTS, FISHING JOB/i, JUNK IN HOLE A.ND SIDE-TI~ACKED HOLE AND A~NY O~-I~R SIGNIFICANT CH2%NGF. S IN HOLI/: CONDITIONS. Spud 1 January 1971 Drill 36" conductor hole~ to 60' Complete drilling rig move from West Kavik Complete Drillsite~and airstrip construction Rigging up Drilling equipment CONFIDENTIAL FEB 1F371 DIVISION Of' OIL AS~D GAS ANCItORAGJ / ~4. ! here/by eertify/tlx,'~gr th.~-f, gregoing/i~,.%rue'~nO ~ ~ / I II I I I I I II I I IIII III I NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must ~ filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. .~.o orr, cE_Fair_banks ........... · E^sE NUM,E,Q2_!_2_7_.0_ ................... UNIT .... Z<emik .......................... LESSEE'S MONTHLY REPORT OF OPERATIONS The followinff is a correct report of operations and production (includin~ drillin~ and producin~ wells) for tl~e montl~ of ..... ~_~--~_~-_~Y_ .................... ,19_~.1-_, ..K___e__~__$.~_____U__~__i_~_____N__o.-,__i-_ .............. : ....................... _4.__2_ ..... :L__:'_._ ' ............................................................ ~lEent'saddress 5 G ~_~_, ...... S.~[.~__.~[~) .............. Company Forest Oil Corporation ..... __~___.c__~__.o..~._.~_~__e_z____~__l___~_.s_.~_~_- .... .~__9__~.0.__1_ ............................... $i ~ned ................................................................ Pl~one ___2__7__.9__-__~_5_J_7_ .............................................................. J~ent' s title D.__J:_v__:__._?__r__o___d__:___~_~._:_ ................... WELL DxYs CU. FT. OF GAS GALLONS OF BARRELS Or REMARKS SEC. AND TWP. RANGE NO. BARRELS OF OIL GRAVITY GASOLINE WATER (If (If drilling, del)th; if shut down, cause; ]4 OF ]4 P~o~vc~. (In thousands) date and result of test for gasoline RECOVERED none, so state) content of g~) ,, , Spu~ i ~anuary 1971 - Drill 363onductoz I~! Com~let~ drilling rig move ~rrom ~est KavJk Comple%~ Dr.llsite ~nd airs~:rip construc~lon ~. ' I SEC · co~ ~D~TZ~L .~_ ,~ I' , ~, -: CONFIDEN1 '\____ -- -- ~ ~/~;~N°?~'were .~;.~_.'_ ...... ~_~.~_ ............ runs or sales of oil; .............................................. M cu. ft. of gas sold; ~___~;~____~/____~_:>~___~ ~ J_~.z~/~n~NY~ Jales of gasoline during the month. (Write "no" where applicable.) ~'~oT~E~.--Re~oort o~'~n~s~o~m is require(~ for each calendar month, regardless of the sbaius of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by ~he supervisor. Forna 9-329 u.s. GOVERNMENT PRINTING OFFICE:1964--O-729-784 (January 1950) ~ ~o. P-~ STATE C~F ALASKA SUBMIT IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF :DRILLING AND WORKOVER OPERATIONS 1. O,L 0 G,~ J'~J ' OT~rZ~ WSLL ~. ~ o~ o~o~ FOREST OIL CORPORATION ~ ~~ o~ o~o~ ~10 Ft~ N~ttonal Bank 81rig. 1900' FEL 1800~ FSL SE ~ Sec 17 TiE R20E Umi;~t Meridian ·API NI/i%~ERICAL ~ODE No. 50-22~-20006 LEASE DESIGNATION AND SEEIAL NO. Kemtk Unit - Fairbanks 021270 IF INDIA]~, ALOTTEE OR TRIBE NAME None 8. UNIT,F.~RA~ OR LEASE NAJV~E Kemik 9. Ww. LL NO. 1 10. FID AND POOL. OR %VILDCAT ~ W~Id~at 11. SEC., T., R., 1%~., (BO/'rOM HOLE OBJF~r~ Sec l? ,TIN R20E U.M. 12. PEHMIT NO. 70-60 13. REPORT TOTAL DEPTH AT END oF MONTH, CI-IA~NGES IN HOLE SIZE, CASING A/~-D CE1VIENTING JOBS INCLUDING DEPTH SET ~ VOL~S USED, P~O~TIONS, ~TS ~ ~SULTS. FISHING JO~, J~K ~ HO~ ~D SIDE-T~C~D HOLE AND ~Y O~R SIGNIFIC~T ~~ ~ HO~ ~ITIONS. Report as of December 31, 1970 Building Drilling Site & Drilling Piling Holes - Rigging Up Bucket Rig To Drill 36" Conductor Hole - Moving Rig Camp From West Kavik - -lc. G oL I c. -,]-'"4 ~NG --~"~" g~OL j--- I ~EV I 'CONFER: FILE: 14. I hereby ce~y/~at the foregoing is true and correct /~_..~../~,F"'F'; ~.~.~.~L... =~_~ ASs't,, Div. Prod. Mqr.~^= 1~ J~nUarV 1971 $IGN]~D NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be file(l in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. tl,u,f. HO,~G~ ~$02 C. GEoLT~ Hr. Ted G. Bingham, Chief Division of Lands and Hinerals Program Management and Land Office 555 Cordova Street Anchorage, Alaska 99501 December 8, 1970 Re: Kemik Unit No. 1 Forest Oil Corp., Operator SEC CONFEi~] FILE: Dear Mr. Blngham: In reference to the subject exploring oil well drilling location in Section 17, Township 1 North, Range 20 East, U.M. The Alaska Department of Fish and Game is concerned about this location as: (1) it could be too close to Fin Creek, a tributary to the anadromous stream, Juniper Creek, and (2) in view of the water requirements for this location, the water source should not be one where withdrawal would adversely affect fisheries waters. I would appreciate information pursuant to these concerns. 'S: erely yours.",// Babitat Development Section ASFS6 cc: J..Blum J. Bergstrand S. Grundy H. Burrel DWi. SiON Of O]L AND GA5 ANCHOP. AG~. ~r In ~m~mt of m~u~fem e~ ~~mmnt please m~f~ ~fs ~flce ~~ly tn ~ L. ~r~ell ~: Dlpirtllllt Of F|IJl II~ i IlO I~C|. FOREST OIL CORPORATION November 17, 1970 Mr. Homer L. BURRELL Chairman Alaska Oil and 6as Oonservation Oommittee 3001 Poroupine Drive Anohorage, Alaska 99501 Dear Mr. Burrell: Enclosed with this letter is our Application For Permit To Drill the ½emik No. 1. The Designation of Operator will be sent separately by BP Alaska, Inc. I trust that with submission of these forms, everything is in order to provide for issuance of the Drilling Permit. Sincerely, H. E. SNIDER Division Production Manager HES:ww STATE O.F ALASKA SUBMIT IN ?RI! -jlt'J[~, (O~her instruetA~ reverse I~lJl) A.P.I. No. 50-223-20006 OIL AND. C-AS CONSERVA,TION ,COMMITTEE APPLICATION FOR PI~RMIT TO DRILL, DEEPEN, OR PLUG BACK "' ,. ~.,~,.~-.~,~.,~NA'~O. ~ ~.o. ~. ~ o~ ~o,~ F~rbanks 021270 DRILL ~ DEEPEN ~ PLUG BACK ~. T~= or w=~ None WJLL WZLL OTHJ~ ~X ZO~ 8. UNIT, FA~ O~ LEASE ,NAME ~. ~ o~ o.~ro~ HEMIH UNIT FDREST ail DaRPDRATIDN ~. ~s~o~~ ~lO 1st National Building 1 ~~ 1900 FEL 1BO0~ FSL ~ildca~ SE~ Sec 17 TIN ReOE Umia~ Meridian .. ~c., ~.,~.,~., ~o~o~ ~o~m x~o~.~o~. ~o.~ TIN ReOE U.M. Same ~2. ~IS~C~ I~ ~I~S ~ ~I~O~!O~ ~0~ ~A~S~ ~0~ O~ ~OS~ O~I~* 1~. }~5~ miles No~h of Fairbanks NO~h Slope ~a%zon~zoe Ha~fo~d Accidem~ 8LM 15. DISTANCE FROM PROPOSED* JiB. NO. OF A~ IN LEASE 17. NO. AC~$ ASSIGN~ LOCATION TO NEAREST I TO ~iS WELL ~o.~RTY OR =~S~ L~. rT. (AI~ tO nearest drig, unit, if any> 3380' 1914, 640 18. DISTANCE FROM PROPOSED LOCA~ON* ] 19. PRO~S~ D~ 20. ROTARY OR CABLE 'fOOLS TO NEAREST WELL D~ILLING, COMPLETe. OR APPLIED FOR, None 13,000 Rotarv 21. ELEVATIONS (Show whether DF, RT, ~R, etc.~ ~. APPROX. DATE WORK WILL, START* 1300~ aR - Tono Map Data - hctual to be. datm~minad 1 Omcmmb~r 1970 SIZE OF I-IOLE SIZE OF CASING WEIGHT PER F°OT GRAD~ t t S~G DEPTH " QUANTI?! Or C~MEN~ . 3~" . 3D" DD 98.93 8~" 7" OD 29,00 MUD PROGRAM 80PE PROGRAM Freshwater Gel - Chemical 0-750' None 0-2700w 9.0-iO.Oppg 750-2700~- 20"-2000 psi 2700w-I3,000~ 9.5-i0.5 ppg 2700-10,500-12"-3000 psi Narker- Estimated Depth- ~" - Okpikruak 0-~000' ~ingak ~hale ~000-8000 , ' ...... 5adlerocB~ 8000-10.000 ' I ~i,~;~.',', ~.;r C~ i..~F) ~AS ~' ne~ Droduc%ive zone. If ~ro~l ~ ~ drill er ~n d~.o~ly,, ~ve ~en% ~ue ve~l de~. Give bl~t ~reventer D~am. ~ovembe~ (Th~ spa~ for S~te olli~ u~) COND~ON~ OF ~V~ i SAMPL~ AND CO~ CHIPS H~U~ vm ~.o SEE T~NSMITTAL LETTER. Division Production Manager November 23.,. 1970. _ . . DAr= N.0~.embe-r 23, 1970 f I II I/ ,q.~O E 18 I I I I I I I I I I I 5 I 4 ~ 3 ! I I I I I I ~ ...... +-- --r ..... I I I I I I I I I 8 I 9 I ~0 I I I I I I I 1 1 I I I I I 19 3O I I 2O 29 KEMIK Lat. 69° 26' Long_:.14?° 15' 57.88" r y: 5,646,138 l I X = 337,150 ] I I I I I 21 I 22 I 23 I I I I I SCALE: I"= IMILE CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct. Date SURVEYOR TIN. KEMIK NO. I The SE I/'4 of Protra Located in Surveyed for FOREST OIL CORP. Surveyed by F M. LINDSEY I~ ASSOC. LAND ~ HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska CHECK LIST FOR NEW WELL PERMITS ComPany t/~~y 7 Lease & Well · Is well to be located in a defined pool ................. Yes No Remarks 2. Do statewide rules apply ........................ y/~ . Is a registered survey plat attached .................. Is well located proper distance from property line ........... /~T 5. Is well located proper distance from other wells ............ ~/~d~ 6. Is sufficient undedicated acreage available in this pool ........ y~ 7. Is well to be deviated ......................... ,~.j~ 8. Is operator the only affected party ................... ,:~,~ g. Can permit be approv~ before ten-day wait ............... -force lO. Does operator have a bond in ................... ll. Is conductor string provided ...................... 12. Is enough cement used to circulate on conductor and surface ...... 13. Will cement tie in surface and' intermediate or production strings 14. Will cement cover al! possible productive horizons ........... 15. Will surface casing cover all fresh water zones . . . : ........ 16. Will surface csg. internal burst equal .5 psi/ft, to next string 17. Will all casing give adequate safety in collapse and tension ..... 18. Does BOPE have sufficient pressure rating .............. Additional Requirements: Approval Recommended: TRM ~; HWK ~) ~< LCS