The URL can be used to link to this page

Home My WebLink About192-009 ON BEFORE 1 2000 N c:LO~LWto°c PLUGGING &/'LOCATION CLEARANC~ REPORT State of Alaska .~zx orn ~ ~ ¢o~s~w~zo~ com~ssmo~ 24emcrar_.du~ To File: APl Operator Spud: , Abnd Date Completed Note casinq size, wt, depth, c=~ vol, & procedure. Liner: Per-= innaL-ra!s - tops: Review the well file, and-cc--~ent on plugging, well head s~atus, and location clearance - provide loc. clear, code. ~arker ~osC or plat~: Yo~ - Code · o PERMIT 92-009 92-009 92-009 AOGCC Individual Well Geological Materials inventory DATA T DATA_PLUS DRY DITCH D 100-2416, SS~ 837 EWR/GR-MUD L 150-2400 MUD L 115-2400, COLOR 92-009 MUD PULSE TELEM L 115-2400 1 407 R COMP DATE: 03/21/92 DAILY WELL OP R 02/10/92-03/22/92 MWD DIRECTIONAL R 195-2387 5289 T 115-2416, OH-MWD*** 92-009 92-009 92-009 92-009 Page' i Date' 02/08/94 RUN DATE _,ECVD 05/05/92 06/04/92 04/20/92 04/20/92 04/20/92 04/20/92 04/20/92 06/08/92 Are dry ditch samples required? ~ no And received?~ no Was the 'well cored? yes/~~alysis & description rece. ived? Are well tests required?~eceived?~~ ~ Well is in compliance ~ ~- ~ I itia Comments ! ~ ~ O'~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4614 D. J. Ruckel KRU/CI/NV Drilling Manager December 11, 1992 CONFIDENTIAL Dave Johnston State of Alaska Alaska Oil and Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, AK 99.501 Dear Mr. Johnston: Attached for your information and files is a summary of the Cirque #1 blowout of February 12, 1992. As pointed out in the summary, there is not one single event that led to the blowout, but rather a combination of events that collectively resulted in the loss of control of the well. The principle causes were: encountering a productive sand (K-10) with a 10 ppg pore pressure at a higher than expected depth, trip speeds that were too high causing swabbing, and hole fill practices that were less than adequate. While it is important to note that the diverter performed its primary function of diverting gas from the rig to allow a safe evacuation of personnel, the length of time it was serviceable was less than desirable. Had the diverter remained effective longer, it may or may not have aided in controlling the well. While the incident was unfortunate, there are several "bright" points. There were no injuries or loss of life. There was minimal environmental damage, and relief well and well kill techniques were proven effective. After an extensive review of the incident, ARCO has made several policy changes regarding our approach to our drilling practices. In addition, we have reemphasized our existing commitment to good drilling practices. While these practices are not directly addressed in the application for the permit to drill, they will definitely be implemented in our upcoming '92-'93 exploration drilling season and all future drilling operations. ARCO has also reviewed the design of the diverter system and has attached an analysis for your information. As the opportunity presents itself, ARCO will be implementing design changes to the diverter systems used in our drilling programs. ARCO would like to thank the AOGCC for its support during the incident, and in particular the onsite people provided by the State. They were extremely helpful throughout the process. In closing, we would like to reaffirm ARCO's commitment to the safe exploration and development of Alaska's oil and gas resources. Sincerely, Douglas J. Ruckel enc. CONFIDENTIAL RECEIVED DEC 1 6 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage ARCO Alaska, inc. is a Subsidiary of Atlantic Richfield Company L CIRQUE #1 BLOWOUT SUMMARY CONFIDENTIAL ARCO's Cirque #1 well was an exploratory test located 12 miles southwest of the Kuparuk Field in the Colville Delta Area of the North Slope of Alaska. The well was spudded on February 11, 1992 using Doyon Drilling Inc.'s Rig #14. The well had been drilled to the surface casing point at a depth of 2,415' and short-tripped without incident on February 12. At approximately 7:10 pm on February 12, while pulling the drill string out of the hole to run surface casing, the well began flowing and subsequently blew out. The bit was at 765' at the time of the blowout. The diverter was actuated to direct the flow of mud and gas away from the rig floor. The well kicked out all of the drilling mud and flowed large volumes of gas and formation material. Initial attempts to pump into the well from the rig floor immediately after it was diverted were unsuccessful. The diverter lines were rapidly cut out in the substructure area by the large volumes of sand and gas being produced. Due to the free gas in the substructure and drill floor areas, all the rig power had to be shut down and all of the personnel were successfully evacuated. There were no injuries and all personnel were accounted for. The well continued to flow at a high rate with the gas venting to the atmosphere but there were no fires or explosions. Since the well flowed only dry gas and formation material there was no pollution. There was no way to measure the flow rate of the gas flow. Response organizations were immediately established at the drill-site, in Kuparuk, and in Anchorage. Additional support was drawn from ARCO's research personnel in Plano, Texas. Mobilization of equipment and manpower were initiated to begin preparation for well control efforts and for the drilling of a relief well. Dowell pumping equipment and tanks were mobilized for the well control work. A second ice pad for the relief well was constructed 1,000' to the north of the blowout and Doyon Rig 9 was mobilized from Prudhoe. Safety Boss Personnel, well control specialists from Calgary, Canada, were contracted and arrived on the Slope to provide expertise and man-power in well control. Flow from the well subsided after the first 24 hours. On February 14 an attempt was made to pump CaC12 kill brine down the drill pipe from the back of the rig. This was unsuccessful because the drill string was plugged. On February 18 the first attempt was made to fill the hole from the annulus side. 1250 barrels of kill mud were pumped into annulus with no effect on the gas flow rate. A second attempt to top fill the hole from the annulus was made on February 19-20 when 1750 barrels of mud were pumped. This did not have any effect on the gas flow. It is concluded that most of the mud pumped in these attempts was blown out of the well by the gas. While these kill attempts were being made, Doyon Rig #q was mobilized to the relief well ice pad. The relief well was spudded on February 22. The gas flow from the well greatly increased on February 24 and the diverter spool was cut out. RECEIVED DEC 1 6 199 By February 27 the gas flow had dropped off to a very low rate. On February 29 the blowout was successfully killed by remotely pumping 3150 barrels of kill mud down the drill string to fill the hole. Operations on the relief well continued and the well reached TD on March 1. The Doyen 14 rig was moved off the blowout well and Doyen 9 was moved on to re-enter the well. After pulling out the old drill string, 9-5/8" casing was set at 709'. BOP's were installed and the well was cleaned out to 2151'. The well was plugged and abandoned by cementing the entire open hole interval. The relief well was not required and was later plugged and abandoned. The Review Team did not find a well defined single cause of the blowout but concludes that several direct and indirect factors lead to the situation. The direct factors were that the mud weight was insufficient to control the shallow overpressured K-10 sands which were penetrated high to prognosis. This combined with high trip speeds and poor hole filling practices allowed the well to be swabbed in. Indirect contributors to the blowout were the "tight hole" aspects of the well which inhibited communication between the Exploration and Drilling personnel, the rig crews unfamiliarity with exploration drilling, the premature spud of the well, and the use of a poorly designed diverter system for exploration drilling. RE( EIVED DEC 1 6 1992 Alaska Oil & Gas Cons. CommiSSiO~ Anchorage CIRQUE #1 REVIEW Introduction: The Cirque #1 well was part of a three well exploration program in the Colville Delta area. The actual surface location is twelve miles southwest of the Kuparuk 2M drill-site (Figure 1). Ice road construction began at the end of 1991 and the drilling was scheduled for January through April 1992. The primary geological objectives of the wells were based on deeper horizons and did not include the shallow intervals that are the subject of this review. The other two wells in the program were the ARCO Tarn #1, which was drilled just prior to Cirque, and the Iceberg prospect which to date has not been drilled. The nearest offset well for planning purposes was the ARCO Bermuda #1 which had been drilled the previous winter approximately 5 miles northeast of the Cirque surface location. Additional offset information was available when the ARCO Tarn #1 well, located 4 miles to the north of Cirque, was drilled just prior to moving onto the subject well. The Union Kookpuk #1 well, located approximately 12 miles to the north-northwest of Cirque, was drilled in 1967. The formations anticipated in the Cirque well through the shallow intervals (down to ~3,500') were expected to be similar to those seen in the Kuparuk Field. This includes the extensive West Sak sands that are found just below the permafrost along with the K-10 and K-5 shale markers. The regional dip would predict those horizons to be found shallower in the Cirque well than seen in Kuparuk Field and in the Bermuda #1 well. The base of the permafrost was expected to be at 1,130' MD. The geological prognosis did not predict the location of the West Sak but did call for the K-10 shale marker to be at 2,830' MD. In Cirque #1 the K-10 marker was actually penetrated at 2,350' MD. Because of an upcoming lease sale, the Cirque #1 and the other wells in the program were considered extremely confidential and a strict "Tight-Hole" policy was established to maintain confidentiality. Following formal bid request and evaluation, Doyon's Rig #14 was contracted for the three well exploration program. Doyon 14 had been stacked since April of 1991. Prior to that the rig had worked exclusively in and around the Kuparuk River Field since it was first mobilized in August of 1987. Over that 3-1/2 year period the rig worked on six wells outside of the unit of which two were shallow tests targeting the West Sak and Ugnu. Doyon 14 was mobilized for the Tarn well on January 17, 1992. Following the rig move from the Tarn location the Cirque #1 well was spudded on February 11, 1992. RECt iVFD DEC t 6 199~ ~laska Oil & Gas Cons. Oommissio~ lln~h~ronz~ SEQUENCE OF EVENTS Rig Doyon #14 was moved from the completed Tarn #1 well location to the Cirque #1 well location on February 10, 1992. Both wells were Exploratory prospects. After basic rig-up the Rig was accepted as operational on Cirque #1 at 22:00 hrs, February 10, 1992. The diverter system was installed and function tested on the 16" conductor casing set at 115' Rotary Kelly Bushing (RKB). The system consisted of a 21-1/4" HYDRIL Model GK Annular Preventer, a 20" diverter spool with two 10" outlets, two CRANE "knife" type hydraulically controlled diverter valves, and two 10" schedule 40 diverter lines. Due to the rig's development drilling history in the Kuparuk River Unit, where Drill Site well configuration dictates diverter line routing, both diverter lines were run out from the front of the unit, parallel to each other. In order to have this configuration three, 90° elbows are incorporated into each diverter line. The diverter system was hooked-up so that when the annular preventer is closed one of the two hydraulically operated diverter valves automatically opens. If required, the second valve can be actuated and opened remotely using a separate control function. At this point the initial bottom hole assembly (BHA) components - Logging While Drilling (LWD)/Measurement While Drilling (MWD) Collars - were picked-up. A 12-1/4" bit was made-up directly into the bottom of the LWD collar. Other applicable BHA components, which included two stabilizers, were picked-up while running in the hole to 115'. After a 1 hour delay repairing/working on a cuttings separator, the well was spudded at approximately 07:00 hrs, February 11, 1992. The hole was drilled vertically in 32 hours without any major incident, to total depth (TD) of the surface hole section at 2415' measured depth (MD). The Well Plan called for surface casing to be set at 2400'. Mud weights utilized for the majority of the interval were 9.1 - 9.2 lb/gal; at TD the mud weights were 9.2+ lb/gal in, 9.3+ lb/gal out. There was no excessive gas encountered through the drilled interval, other than the normal "peaks" associated with West Sak sands (300 - 400 units). Background gas was 75 - 100 units. At 2415' a bottoms-up was circulated. Bottoms-up and maximum gas was +/- 170 units, which included gas from a 10' section of K-10 sand drilled immediately prior to reaching TD. A 13 stand short trip was made to 1130', the top of the 5" Hevi-Wate Drill Pipe (HWDP). The hole was extremely tight off bottom and the first 9 stands in particular had to be worked extensively before a stand could be broke out and set back. During the trip out, the hole was reportedly being continuously filled from the trip tank. The Sperry Sun mud log strip chart, because of an apparent malfunction in their sensor above a level equating to 12 barrels, did not indicate any fill from the trip tank. Another interpretation of available data (the strip DEC 1 6 !99 ~laska Oil & Gas Cons. Oommissio~ ~n~hnr~rm chart) indicates a possible continuous fill from the active system. This is contrary to the driller's statement. The rig's flow show charts indicated that there was definite swabbing on the trip out, however the driller stated that after all pipe had been pulled the hole had taken the correct fluid to fill. The trip back in the hole to 2415' showed the hole to be in good condition. No fill was reported. After the short trip a bottoms-up was circulated. Notable gas was at surface basically as soon as circulation started. Maximum gas recorded during the circulation was 2448 Units. The entrained gas caused a mud weight reduction to 9.1 lb/gal. This information was conveyed to the ARCO Drilling Supervisor, by telephone, and the Doyon Field Superintendent, who was on the Rig Floor. It should be noted that February llth was Doyon's crew change and the regular tool pusher had not yet arrived on location at this time. Once bottoms-up was achieved the gas decreased normally to a background reading of approximately 100 - 170 units. Circulation, with the degasser running, continued while the Milpark mud engineer completed a mud check he had started at the beginning of the circulation. The mud check is a normal practice done prior to running casing. A discussion was held between the ARCO Drilling Supervisor and the Mud Engineer, by telephone, on timing for pulling out of the hole. The mud engineer stated that the check would be completed by 17:35 hrs. Circulation continued until this time. The mud weight stabilized at 9.3+ lb/gal. A single shot survey was dropped, then a "slug" pumped. The driller stated that the trip tank was filled and lined up on the hole. The strip chart indicated that the mudlogger's trip tank sensor was still not functioning. The kelly was set back and the trip out of the hole to run 9-5/8" casing was initiated. The driller stated that prior to starting to pull out of the hole he observed the well and the fluid level was static. He picked-up and the crew installed a stripping rubber on the outside diameter of the drill pipe. The stripping rubber was kept above the rotary table, using the weight of the roughnecks to keep it at rotary table level while pulling out of the hole. One single joint of drill pipe was laid out and remained in the mouse hole. The mud logger strip chart showed that the first 7 stands of drill pipe off bottom were pulled at a reasonable speed. As is normal practice when at a casing or logging point, the drill string was being measured (strapped) after each row of tubulars was stood back. The hole was in good condition and the driller, who monitored and recorded the fill-up figures in his tally book, stated that the hole took the correct amount of fluid to fill. The rig's flow show chart indicated there was continuous flow down the flowline during this period supporting the driller's statement that the hole was being filled continually. The mud logger's REEEJVED DEC 1 ~ !99~ ~,laska Oil & Gas Cons. Oommissio~ strip chart showed no fill-up was occurring, neither from the trip tank (sensor not functioning) nor from the active system. The designated "pit watcher" was in camp eating during this time, however as is historically the case on drilling rigs, it is an assumed conclusion that an alternate had been assigned and was in the general mud pit area during the trip. It should be noted at this time that the basic mud pit design on Doyon #14 is not conducive to on the spot monitoring of trip tank levels. There is a 7' "dead space" between the main floor grating in the mud pit room and the top of the grating on the mud pits themselves. In addition there is no visual level measurement deviH installed in the trip tank; the pit watcher counts rungs on the tank access ladder. The rungs are at 1' intervals, and the known capacity of the trip tank is 5.3 bbls/ft. The next 6 stands of drill pipe, to the top of the HWDP, were pulled at high speeds: 6 stands in slightly over 8 minutes, slip to slip. The driller stated that this is normal pulling speed, and that the hole had taken the correct amount of fluid to fill. The last of the drill pipe was strapped at this point. Four stands of 5" HWDP were then pulled and stood back. With the fifth stand approximately two thirds out of the hole the driller noted flow on the driller's console flow show. He ran the stand back to rotary table level, picked up to get the stripping rubber out of the line of sight and he and the floor crew visually monitored the well. The bit depth was 765'. The well kicked hard immediately at this time (approximately 19:30 hrs, February 12, 1992) unloading large amounts of mud and debris on the rig floor and derrick area. At this time the rotary bushings were blown out of the table. The driller made his way to the "dog house", which is located directly behind the driller's console area. The diverter system actuating controls are located in the dog house as is one of the two handset intercom telephones which are located on the rig floor. The driller used the intercom telephone first call the Doyon Toolpusher, who had just arrived on location from crew change, and told him the well was flowing or blowing out. He then called the ARCO Drilling Supervisor and told him the situation, adding that he was going to put the well on diverter. The Drilling Supervisor told the driller to do this immediately. At no time did the driller activate the diverter system. On hearing that the well was blowing out, the Doyon Toolpusher ran from the change room/coffee room in camp to the rig floor. He entered the dog house and activated the 21-1/4" annular preventer and therefore one diverter valve. Immediately after doing this he activated (opened) the second diverter valve. The elapsed time between when the well blew out and when it was put on diverter was approximately 5 minutes. ~ E C E IV ._F EO ] G !,992 Alaska O~t & Gas Cons. 6ommission Anchoraee After the well had been diverted and all flow to the rig floor had ceased, the rig crew installed a drillpipe screen in the top joint of 5" HWDP, stabbed and made- up a drill string safety valve, and rigged-up surface lines for a pump-in operation. By this time the ARCO Drilling Supervisor had arrived on the rig floor. The Doyen Toolpusher went to inspect the cellar area. All non-essential personnel were evacuated from the rig floor. The driller turned on a mud pump and brought it up to maximum strokes per minute. He noted the pressure was in excess of 4000 psi (pressure relief valve was set at +/- 3700 psi) and slowed the pump so that the pressure was in the +/- 3000 psi range. He continued to pump. The driller stated that total of 35 barrels mud was pumped down the drill string. The Doyen Toolpusher, on his inspection, noted that one diverter valve body was cracked, diverter lines were beginning to cut-out and there was free gas in the cellar area. He ran back to the rig floor. The pump-in operation was suspended. The rig was evacuated of remaining personnel and the Emergency Rig Shut-Down activated. The time was approximately 20:00 hrs, February 12, 1992. A survey was conducted in the camp area immediately after the event to ensure that all personnel were safe and accounted for. This proved to be the case. There were no injuries reported. RECEIVED DEC 1 ~ ~ Alaska Oil & Gas Cons. 6ora~iss~Of~ Anchorage L.INFIDENTIAL ANALYSIS OF PROBABLE CAUSES OF BLOWOUT - CIRQUE #1 The review of the data and the results of the interviews with the personnel on location do not result in finding a definitive single cause for the Cirque blowout. It is apparent that since the well was successfully drilled to 2415' and short tripped without incident that some basic mistakes were made in the rig operations during the final trip out of the hole. Rather than a single cause, the review team believes that poor drilling practices for Exploration drilling combined with some extenuating circumstances led to the well blowout. The primary cause for the blowout is attributed to excessive trip speed which swabbed the well. The swabbing effects were possibly aggravated by bailing on the bit and stabilizers. The mud weight and trip margin were insufficient to offset the swabbing effects. The drill pipe was being pulled at speeds of up to 300 feet per minute at one point. Maximum pulling speeds of 200 feet per minute were recorded while pulling most of the drill pipe stands. The driller described this trip speed as normal for the rig and normal for operating in the Kuparuk Unit. These high trip speeds have been accepted in the KRU development drilling operations where there is more control and understanding of the geology, fluid saturations, and pressures. However, the review team believes that these trip speeds are excessive for drilling below a diverter in an Exploratory well where the geologic control is substantially less. The other probable cause of the blowout is poor hole fill and monitoring techniques on trips. There is no data that definitely shows whether the hole was being filled or was not being filled. If the hole was being filled, the chart recorders don't indicate whether or not the hole was taking the proper amount of mud. The monitoring of the hole fill up was poor. The driller was not using an ARCO trip sheet, the pit watcher was eating and was not monitoring the trip tank, the fillup volumes were not being called out, the mudloggers were not actively monitoring the hole fillup, and the mudloggers trip tank monitoring system appeared to be not working properly. To add to the confusion, the drilling contractor has used different methods of filling the hole. On the Tarn #1 well for example, the drilling contractor used the following three methods to fill the hole: continuous fill from the trip tank, continuous fill from the active system, and hole fill up every 5 stands from the active system. This caused the Sperry mudloggers to be confused about how to monitor the hole fillup volumes. On the Cirque well, the driller stated that he was filling the hole continuously from the trip tank and that the hole was taking the proper amount of fillup. The mudloggers strip chart of the surface monitoring systems does not show that the hole was filled from the trip tank but the accuracy of the Sperry trip tank monitor is suspect due to its response character. An additional factor which caused the problems in the Cirque well was penetrating a K-10 sand in the 12-1/4" surface hole. The Cirque Well Plan called for setting the 9-5/8" surface casing below the West Sak sands and ab~v~ ~e~-v ED 6 !992 Gas Cons, i.,ummJB'~Jo. 10 marker. This is the usual surface casing setting depth in the KRU. The geologic prognosis for Cirque showed the top of the K-10 interval to be at 2870' RKB (-2700' SS). However, the top of the K-10 interval actually came in 520' high at 2350' RKB and the first K-10 sand came in at 2405' RKB. The Cirque well drilled 10' into a K-10 sand. The K-10 sands are river channel deposits and are not continuous through out the field. They show up in some wells and are not present in other wells. The K-10 sands have contained some oil within the KRU and have been occasionally slightly over pressured. The Union Kookpuk #1 well (8 miles NNW of Tarn and 12 miles NNW of Cirque) took an oil and gas kick from the K-10 at 2667' RKB (-2603' SS) in 1967. The Kookpuk kick was taken while drilling on bottom with 9.2 lb/gal mud. The kick pressures are not known but the rest of the well was drilled with a minimum 10.5 lb/gal mud weight. Tarn and Bermuda, the closest offset wells to Cirque, drilled the K-10 with no problems. At Tarn one of the K-10 sands was penetrated in the 12-1/4" surface hole with 9.3 lb/gal mud and the rest of the K-10 interval was drilled below surface casing with 8.9 lb/gal mud. At Bermuda the K-10 interval was drilled with 8.9 lb/gal mud but did not contain any sands. The K-10 at Cirque is thought to contain gas. The maximum gas peak while circulating at 2415' after the short trip on Cirque #1 came from the bottom of the hole. The K-10 at Cirque #2 has also showed indications of gas. Drilling into the K-10 at Cirque #1 did not cause a kick, but if the K-10 there is over pressured it would have reduced the trip margin to an unsafe level. Some over pressure in the K-10 was indicated by the RFT pressure data obtained on the Cirque #2 In addition to these probable causes for the Cirque blowout there are extenuating circumstances that contributed to the problem. These circumstances include the tight hole status, over-experience with development drilling, premature spud of the well, and the work load on the Drilling Supervisor. The Colville exploration wells were operated as "extremely tight holes" and special practices were put in place to ensure confidentiality. Examples of this are that the logs were to be seen only by well site geologist and top management, the Geolograph recorder was not operated, and the Drilling Supervisor, mud engineer, and the driller did not have full access to the mudloggers unit and information. These practices and the working atmosphere they created inhibited communication of operational drilling information on the rig. This also prevented the ARCO Drilling personnel from learning that the K-10 formation had come in very high compared to the geologic prognosis at Tarn and would likely come in high at Cirque. Had this change in geologic prognosis been commtmicated, the surface casing point may have been revised to ensure that it would be kept above the K-10. The rig and crew had spent almost all their time in development drilling work in KRU and were not familiar with exploration drilling. The drillers, and perhaps the Drilling Supervisor, were not familiar with the mudlogging units and the operational information that can be obtained and monitored. The mudloggers ECEIVED had not been given any instructions on what was expected of them from the drilling operations personnel. Communication with the mudloggers was very poor. There was no phone for the mudloggers to talk directly to the Drilling Supervisor or the driller. The only communication the mudloggers had with the driller was a squawk box. The Cirque well was spudded prematurely in that the surface hole was being drilled before the camp was set up and operational. This meant that the Drilling Supervisor did not have an office and was working out of his truck during the early stages of the well. The camp was operational prior to the blowout. The mudlogging contract included a remote monitor for the Drilling Supervisor's office which should have been available but the monitor was just being rigged up at the time of the blowout. The drilling contractor explained that the camp is usually moved first but that on this particular move from the Tarn location the access to the camp was blocked by the rig so that the rig had to be moved first. The rig was up and running before the camp was moved. The workload on the Drilling Supervisor is very heavy during the drilling and casing of the surface hole. This is especially true for the Doyon 14 rig. This rig is unique in that it is fully contained in one module compared to the other rigs that have several modules. This means that the very little rig up work is required after a move and that the rig is essentially ready to drill when it gets to location. This does not provide the Drilling Supervisor much time to organize and line out all of the various support operations prior to rig acceptance. The total time to rig down at Tarn, move to Cirque, and rig up was only 12 hours. This is a very efficient system for development drilling where all of the support systems are already in place but there is more work in getting an operation started when it is out of an established unit. RECEIVED Alaska Oil & Gas Cons. Commission' Anchorage CONFIDENTIAL CONCLUSIONS AND RECOMMENDATIONS Conclusions: The Review Team concludes that the rig crews familiarity with Kuparuk development drilling operations coupled with the close proximity of the Cirque well to the Kuparuk River Unit led to the use of those same development drilling practices and equipment in the exploratory drilling program. The use of these practices, when combined with the existence of unexpected gas sands in the surface hole, led to the uncontrolled flow from the Cirque #1 well. The key areas where these factors contributed to the blowout are: · Excessive trip speed in the surface hole. Trip speeds used were "typical of those used in Kuparuk". · Inattention to hole conditions that might have warranted more cautious trip procedures. This included swabbing problems, a significant amount of gas after the short trip and the fact that the gas following the short trip was seen almost immediately after circulation began. While these problems would not have been a sign for immediate alarm in the day-in day-out operations in Kuparuk they should have raised a flag on any exploration well, especially while in a diverting situation. Some measures of caution might have been: increasing the mud weight, a closer watch on the hole fill, slower trip speeds, an additional short trip, etc. · Inappropriate hole fill and hole fill monitoring techniques. A common practice for the rig crew was to fill continuously from the active mud system during trips. Although this was reportedly not the case during the Cirque #1 blowout the rig crew on Tarn #1 had filled the hole by continuous fill out of the 400+ bbl active system. This illustrates the rig personnel's complacency toward monitoring hole fill up. Pit watcher not monitoring fill-up. However, the Doyon 14 pit system does not permit the pit watcher to easily monitor the hole fill. Driller not required to maintain a record of hole fill on standard trip sheet. Mud loggers not actively monitoring hole fill. Furthermore, it has been concluded that the mud loggers trip tank sensor was inoperative on the trip that led to the blowout. Because of the bad trip tank sensor the mud logger's observation was that, on the short trip, the well was nothing..,. [Z| YE D ~\L~LI 9 DEC 1 6 1992 Alaska Oil & Gas Cons. (;omrnissio~ until all 13 stands were pulled. They made this observation but did not query the driller on his use of such improper hole fill procedures, nor did they inform the ARCO Drilling Supervisor. Use of a Diverter system that was modified to fit multi-well drill-sites in Kuparuk. Diverter lines had three 90° turns in each line. While the diverter system in use did not attribute to the actual blowout the nearly instantaneous failure of the diverter line(s) led to the immediate evacuation of the rig limiting the opportunities for re-gaining control of the well. Additional extenuating circumstances included: · Spudded well prior to having the camp set up at the location. Led to increased work load on Drilling Supervisor and mud loggers. Drilling Supervisor unable to be on the rig floor during short trip and ensuing final trip out of the hole. Mud logging engineer was rigging up remote monitor in the Drilling Supervisor's office during the last trip and was not monitoring hole fill up. · Well Plan indicated possibly a less than desirable mud weight for drilling the surface hole. The mud weight and the formation pressure at the TD of the surface hole as shown on the Pore Pressure Plot in the Well Plan would result in only a 25 psi over balance. This would not serve as an adequate margin for tripping if the pore pressure was actually a 9.2 ppg equivalent mud weight (EMW) as depicted. However, for what would be considered as a normal pore pressure gradient (8.6 to 8.9 ppg EMW) the mud weights used should have provided an adequate over balance. · Tight-hole procedures led to poor communications. The Tight-hole procedures in place, whether intentional or not, led to poor communication at the rig. The Drilling Supervisor was alienated by the procedures in place to the point where he felt that he was not allowed in the mud logging unit. This possibly led to the Drilling Supervisors failure to issue instructions to the mud loggers for monitoring hole fill on trips. Poor well control procedures. RE{ E VED 10 DEC 1 g 1997 Alaska Oil & Gas Cons. Com~iSsio~ Anchorage Driller did not exercise his authority to divert the well. He made two phone calls while the well was displacing mud onto the rig floor and never did put the well on diverter himself. Failure to communicate revisions in the Geological Prognosis. A revised prognosis was not provided to the Drilling Department reflecting the information gained in the Tarn #1 well. Had that information been made available it would have shown that the K-10 was several hundred feet shallower than had been originally expected. In planning the Tarn #1 well ARCO's Drilling Engineers had identified that the data from the Union Kookpuk #1 did indicate the possibility of over pressure in the K-10 interval. The K-10 had also been known to be over pressured in certain areas of the Kuparuk Field. This resulted in a casing point selection above the K-10. 11 ,Alaska OiJ & Gas Cot~s. Commissior~ Anchorage Recommendations: · Pre-spud meetings should be held with a review of each crew member's responsibility in a diverting situation. Emphasis should be made that the well is an Exploratory test and that special drilling precautions must be taken to ensure the well is drilled safely. A review of basic drilling practices should be made since certain procedures and practices that are acceptable within the confines of a proven field may not be appropriate in exploration operations. The meeting should include a discussion of the risks associated with drilling the surface hole interval and how the diverter system offers few well control options when compared to drilling below a BOP stack as would be the case in deeper sections of the well. All personnel must be briefed and know their duties. The driller should be briefed on what is expected of him in a well control situation. The driller must understand that he is responsible for the immediate control of the well and the safety of the personnel on the rig floor and that he has the authority to put the well on diverter if the primary signs of a kick have been recognized. The driller must keep an accurate log of hole fill for any trip. The mud loggers must monitor the hole fill and report any discrepancies immediately to the driller and the ARCO Drilling Supervisor. Trip speeds in the surface hole must be conservative, especially when there is any indication of gas in the well. Because of the shortened hydrostatic column available, trip margins are naturally compromised when drilling the shallow section of any well. The primary means of compensating for the lower trip margin is to reduce pipe tripping speeds. This becomes especially critical when there are possible gas bearing zones open in the well. The pore pressure plots in the Well Plan must accurately reflect the expected conditions. Any possibility of abnormal pressure should be thoroughly documented and incorporated into the Well Plan, especially when the over-pressured intervals are above or near the planned surface casing setting depth. Drilling and Geology must keep an open line of communications regardless of the "Tight-hole" aspects of the well. .~ E ~ E ~Y ~ D 12 DEC 1 6 !99~ Alaska Oil a Gas Cons. Commissioo Anr~h~r~n~ Any revision in the expected tops of formations in any section of the well should be made known and the implications of the revision discussed. Diverter lines should be straight without any turns. All applicable rig and service company monitoring equipment should be calibrated and operational prior to spudding. 13 RECEIVED DE¢ 1 6 199C Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc Date: October 29, 1992 Internal Correspondence Subject: Cirque #1 Diverter Analysis and Recommendations From/Location: L.R. Crane / ATO 1410 Telephone: 265-1544 To/Location: D.J. Ruckel / ATO 1420 The purpose of this document is to present an analysis of Doyon 14's diverter system as installed while drilling the ARCO Cirque #1, an analysis of the diverter systems failures, and to propose recommendations for future diverter systems. The focus will be on the diverter spool, outlets, valves, lines, and controls. Cirque #1 Diverter Installi~tion The following schematic lays out the geometry of the SYstem as laid out on Doyon 14. The diverter spool was a 21-1/4" 2000 psi spool with two 10" 150 psi flanged outlets located East and West, 180© from one another. Directly on the 10" outlet flanges, two 10" 150 psi hydraulically operated knife valves were installed. These valves had to be hydraulically pumped open and pumped closed. They were not fail-safe one position or the other. (Actual lengths of the various sections of the vent lines were not documented. The lengths quoted below were estimated from photographs. ) It should be noted that all 90© turns in the diverter lines were obtained by using 'targeted' (or 'plugged' or 'dead leg') tees, The plugged ends were not fitted with sacrificial targets of lead or any erosion resistant material. The West side diverter line elbowed down to within about 3' of the ice pad and out toward the front of the rig at about a 30° angle. At that point it elbowed and went straight West out the side of the substructure walls. Approximately 3' outside of the wall the line elbowed to the South and remained about 3' above ice pad level for its remaining +/- 45' of length. The East side diverter line elbowed down nearly to the ice pad and out toward the front of the rig at about a 30© angle. At that point it elbowed and went straight East out side of the substructure walls. Approximately 3' outside of the wall, the line elbowed to the South and down to the ice over about a 5' length. At that point the line elbowed back to the East for approximately 50' and remained at ice pad level. At this point it elbowed back to the South for its final +/- 45' of length. The rig controls for the diverter system simply opened the first diverter valve (East side) and shut the annular preventer simultaneously. The second diverter valve had a dedicated control that could open or close it. The first diverter valve could only be closed by opening the annular preventer simultaneously. All indications are that the control system for the Doyon 14 diverter system function properly once the decision to divert was made. Diverter System Failures Holes in the original diverter installation were found throughout the vent lines particularly down stream of the eight plugged tees. All holes were the result of erosion due to high velocity gas and sand traveling through the lines during the blowout. There was some erosion at the spool outlets also. How much of this erosion was before and how much occurred after the vent lines were replaced is not known. By far the majority of the erosion in the spool was on the west side and opposite where one of the knife valves was only partially open during part of the flow, (on the replacement installation.) The East side valve most likely was never fully open from the point REC[IV[D ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A /~laska, Oil & Gas Cons. Corr~rnissio~ where it was closed to install the new diverter line on the East side. It was only partially open for the majority of the gas flow. * All elbows were schedule 40, welded, plugged tees without erosion targets. Recommendations The following recommendations are derived mainly from researching the available industry literature on diverter systems and observations from the Doyon 14 incident on the Cirque #1. When evaluating the options, it is recommended to design for the worst case of dry gas and sand production. Diverter Line Sizin~l Research has shown without a doubt that bigger is better when considering diverter lines and their performance. Fluid (gas) and sand particle velocity are the most important contributors to erosion in diverter systems. Therefore, the larger the diameter of the vent lines, the lower the velocity (and back pressure) will be for a given flow rate. For onshore applications such as the North Slope of Alaska, a single 16" vent line or a pair of 12" vent lines would in most cases be large enough to prevent high back pressures that might be capable of broaching to the surface. Both of these arrangements provide over 200 square inches of flow area which is about 30% greater than the two 10" vent lines used by Doyon 14 on the Cirque #1. Unless the reservoir performance of a blowout is predictable, it is hard to design for the velocity of the gas sand mixture that might be produced through this larger diverter line for erosion considerations. For onshore cases, these sizes would be consistent with present industry direction. Diverter Line Geometry - It is universally accepted that diverter lines should be as straight as possible. Straight lines induce less back pressure than lines with turns (assuming length is constant) and the erosion problems associated with the turns are eliminated. Disturbances in flow due to internal features such as poorly aligned welds in straight sections, valves, poorly aligned flanges, and improper gaskets will cause accelerated erosion wear downstream of those features. For these reasons, quality control during the construction of the diverter system should be a priority. There is a slight controversy over outlet arrangement on the diverter spool. Some feel that having two outlets 180° from one another increases erosion problems in the spool. On the other hand, most field observations and experimentation indicates that erosion starts in the bends and valves and progresses back to the diverter spool. This observation was made in the case of the Cirque #1 as well. If the significant erosion problems are eliminated downstream of the spool, it appears significant erosion in the spool will not be a problem. CC File Cirque #1 A. W. McBride D. R. McKelvey R. F. Morgan D. B. Stoltz ARCO Alaska Inc. is a subsidiary of Atlantic Ri<=hfietd Company AR3B-6001-A RE -EIVJ D ^!aska Oil & Gas (;ohs. Oommissio~ Anchorage 1 O" flanged schedule 40 pipe TT = Plugged Tee, welded Doyon 14, Cirque #1Diverter Schematic RE( EiVED DEC 1 6 ~99~ Alaska Oil & Gas Cons. 6ommissio~' Anchorage Substructure Walls 16" conductor Ice Pad Level · Front View (not to scale) West East Cirque #1 Diverter Installation D rEC 1 6 ~992 Oil & Gas Oozes. 6ommissior~ Anchorage ~ubstructure Walls Top View (not to scale) West East Cirque #1 Diverter Installation RECEIVED DEC 1 6 1997_ ,Alaska Oil & Gas Coils. CommJssio~ Anchorage 12" vent Substructure Walls 12" ball valves if 'SXV' is not used 12" vent Top View (not to scale) Diverter Installation with Two 12" Lines RECEIVED Alaska Oil & Gas Cons. Commissio~ Anchorage Substructure Walls --~ 16" ball valve if 'SXV' is not used 16" vent line Diverter Installation with One 16" Line Top View (not to scale) DEC I 8 ~992 Alaska OJj & 6as Co~s. L;ommissio~ Anchorage ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659-2821 October 21, 1992 Mr. William J. Smyth Alaska Department of Environmental Conservation PCRO/North Slope District Office 3700 Airport Way Fairbanks, Alaska 99709 Certified Mail Return Receipt Requested P 459 406 451 Re: Cirque #1 Exploration Well- Final Report Dear Mr. Smyth: I'm writing to give you the final report on Cirque #1 as requested in your March 10, 1992 letter. Several aerial and land inspections of the site were done in conjunction with standard Exploration follow ups. Enclosed are photographs and maps documenting these trips. Darkened areas on the photographs are primarily formation sands, and compressed tundra vegetation typical of areas after heavy winter traffic. The formation sands were further wind dispersed during the summer, and are expected to be minimal accumulations after next breakup. A close up shot of a typical "heavy" accumulation taken July 9th shows undisturbed vascular plant growth. Scott Mignery and Tim Stevens with The Department of Natural Resources accompanied me September 3rd for the final flyover, both were extremely impressed. I have asked Tim to send you a letter personally detailing his perspective and observation. The vicinity of Cirque #1 exhibits no signs of stress or damage and is dry (free of ponded water) making requested conductivity readings not possible. With these findings as we have previously discussed, AAI would like to close out the above referenced incident. If you have any questions regarding this, please contact Willie Willenbrink or me at 659-7866. S~,rely, Cathe A. Grosshandler/Willie E. Willenbrink Associate Environmental Coordinator Attachments RECEIVED OCT 2 9 199 Alaska Oil & Gas Cons. 6ommissio[~ Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Bill Smyth October 21, 1992 Page #3 Re: Cirque #1 Exploration Well- Final Report CC: Simon Mawson, ADEC PCRO/Anchorage Rick Smith, DNR Ralph Davis, NSB Blair Wondzell, AOGCC 230/01 3.5/mjk 9 July 1992 (CAG) Cirque Well #1 Facing West NOT TO SCALE CIRQUE RELIEF WELL CIRQUE (~RQU£ .- CONDUCTOR AS-BUILT LOCAllON X- LA~--70z OT L ~'~0--1.~0' 2,t.' 1015' F.N.L. S,~I~'T' F~-.L VICINITY MAP sco~.: ,~ .~ ~L AREA WITH SMALL POCKETS OF FORMATIOH PARTICULATE RANDOMLY DISPERSED _ ~__oJ .................... =! ._ ......... :: ................ I ARCO Alaska, Inc. :: : : :_ . C~l ....... --I ............ 74~!_8 I Subsidiary of Atlantic Richfield Company SCAL~: /DAT~: , /CADD F~LE NO. J /JO~ NO: I SUB JOB Nm I D~A~Nc Nm //LOUNSBURY & &3~OCL~'I'I~, ~c. ~ - CIRQUE WELL BLOWOUT REDEFINED IIdPACTED AREAS AS OF SF_P1EI~B£R 1992 DOC. NOT TO SCALE LOk, O-.leO' :re' 1o15' FJ~IJ_. 1.~1' ~c 2~ TIN. R7[ .¢ // / REVISION CONCENTRATED POCKETS OF FORMATION PARTICULATE UGHT FORMATION PARTICULATE SAMPLE LOCATIONS ,,LOUNSBURY DESIGN: JFCR NO: J - -J .... _-_ J ARCO AltlkI, Ino. APPROVAL: AF~/CC NO: ' ' J KM4218 J Subsidiary of Atlantic Richfield Company /-~b-6-h-~. [ - /~ .~' I su~ ~ .~ I o.~.Ng N~ ~ ~/O~/g~J L~DOC75~ J }/g~/~...,J S.t ~2-m5 [ - J DOC. ~-753 QRQUE WElL BLOWOUT REDEFI~ IMP^CTED AREAS As 3/oV92 RE E!v' D 6/5/92 Cirque #1 ~ NW 1:30 pm. 700'AGL 500'R (WEW) 6/5/92 :30 pm. Cirque #1 Looking Norih 700' AGL, 1000' R (WEW) 6/5/92 Cirque #1 Looking SE 1:30 p.m, 700'AGL, 1000' R (WEW) 9 July 92 (CAG) Abandonmerlt Msrker of Cirque 9 July 1992 (CAG) East edge of Cirque pad where Trimmer was used to remove frozen drilling mud 8/14/92 Cirq.u,e #i Lo,°,king N0dh 12:20 p.m. 2000 R, i000AGL (WEw) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 14, 1992 ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Attn.' John Winegarner Senior Landman Re: Location Clearance, ARCO's well ,/Cirque #1, ¢' Cirque #1x, ¢' Cirque #2, ~' Tarn #1 '" West Sak #1 ¢' West Sak #15 PTD-92-0009 PTD 92-0021 PTD 92-0029 PTD 91-0151 PTD 71-0003 PTD 79-0099 Dear Mr. Winegarner: Our representative visited the above locations on September 23, 1992 and found that the marker posts contained the correct data and were in place, locations were clear of materials and debris, and pits had been filled and graded, and that the locations appeared to be in stable condition. Location clearance is hereby approved for the above listed ARCO wells. Sincerely, r~ printed on recycled paper b y C.O. TO: FROM: MEMORANuUM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION ~ave Johnst~ ~ommissionet~ DATE: FILE NO: TELEPHONE NO: September B, 1992 lg9392-9,doc Blair E Wondze±l P. I. Supervisor. SUBJECT: Location Inspection Arco Cirque~l Sec 20,T9N,R7E,[~ Exploratory PTD 92-9 JL~du Grimaldi Petr Inspector S.ugdas~8-23-92 t flew to Arco's remote exploratory location Cirqu.e~)l to perform ~ location inspection for surface abandonment. I found the location to be very clean with no evidence of trash or drilling debris. The marker was of proper size and construction with the following information bead welded on it:ARCO ALASKA INC. Cirque4Pl ADL375076 1015FNL,lgS1FEL SEC20,T9N,R7E,Ubi There is very little evidence of the blowout that occurred on this well last winter. I walked the general area of the vent lines and found two to three small patches of sand and some gravel spread thinly around. Ii feel that in time these will disappear. One area that needs to be addressed is the path of the now thawed ice road between Tarn~] and this location. It appears that the edge markers were left. behind and I feel that before full clearance can be granted, these markers should be removed~ ~ Cirque#l has been cleaned up and I could find n.o evidencc of contamination from the blowout, The markers left behind from the :ice road still need to be removed before clearance can be granted. Doug Amos reports the markers have been removed, therefore location clearance can be granted. 02-00lA (Rev. 6/89) 20/11LMEMOl. PM3 ALASKA 0IL and GAS CONSERVATION COMMISSION Surface Abandonment Report (Title 20 AAC 25, Article 2) FILE INFORMATION Operator: Address: Surface location: /~~' F ~ L, ~' F ~ L Sec ~ , T ~ ~ , R ~ ~ , ~M 20 AAC 25.120 - WELL ABANDONMENT MARKER Steel post: diameter (4" min) /7/ Height above final grade level: {4' min) Top of marker pipe closed with: cement plug~ Set: on wellhead on cutoff csg distance below final grade level Side outlets: all valves & ni removed all openings closed w/blin'ds Information beadwelded directl~ to marker post:. (note where different from file information) Operator: p:£c~> ~~F~ Well Name: C z~d~d~ Downhole P&A date: Permit #: APl ~: Unit or Lease Name: Well Name: Field and Pool: , length (10' min) screw cap.~ in concrete plug I ) II w/cement other Unit or Lease Name: Surface Location: welds /O/~ ' FA/ L, }4~L_ ~-~ ~-o7~ Sec ~0 , T ~ ~ 20 AAC 25.170 - LO~TION CL~NUP Pit~: / / filled in ~/~ -liners removed or buried /Y/m debris removed Surface of'pad and/or location: ............ ~ rough ~ . smooth contoured flat compacted~ Cleanup of pad and/or location: clean pipe scrap iron scrap~ wood mud other Surroundin9 area: wooded brush~ tundra grass dirt Condition surrounding area: clean trash from site I t~.¢" ! , F ~' L .,R7 E,dM other cement paper Access road: dirt gravel ice ~ Condition access road & surrounding: clean~ rough smooth~ trees and/or brush from clearing road other gravel sand REMAINING TO BE DONE: trees and/o~ brush from clearing site trash from operations spoil from clearing road RECOHHEHD APPROVAL OF ABANDONHENT: Yes / No Final inspection C.0010 (rev 05/01/90) TO: DATE: State of Alaska Attn: Larry Grant 3001 Porqupine Anchorage, Alaska 99501 (907) 279-1433 ARCO Alaska Inc. Atl anticRichfieldCompany FROM: C. M. Posey ANO 920A ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 June 8, 1992 Transmitted herewith is the following: Final Cirque #1 LIS tape containing all MWD data Final Cirque #1X GCT Survey, sepia Final Cirque #2 Cement Bond Log, sepia - Final Cirque #2 Selective Formation Tester, sepia .-1'~- Final Cirque #1X GCT Survey, paper ..---t- Final Cirque #2 Cement Bond Log, paper ~ r,,J ~ - Final Cirque #2 Selective Formation Tester, pape Approved for transmittal by: T. ~. Hudson Manager .~ / Kupamk Development and W. Extension Geoscience .~~~,/~-~- Date: ~-'/,~//~~ Receipt: / .~ ~/~ Return rece~.' / / ARCO Alaska, Inc. Attn: Mr. Clifton M. Posey - ANO 920A 700 G. Street Anchorage, AK 99510-0360 (907) 265-6240 wk. (907) 265-1398 fax CMP RECEIVED dLItl 0 8 199~ ,oi1.!~.: Co,~. ARCO Alaska Inc. AtlanticRichfieldCompany TO: DATE: Mr. Bob Crandel AO30C State of Alaska Anchorage AK June 2, 1992 FROM: Transmitted herewith J. E. Sallee ANO 954 CONFIDENTIAL MATERIALS is the following.'_ ARCO Cirque #1 ~.M~WD EWR-GR mudlog ~l~epia, 'l~paper ~aper ~aper :C[IVED Approved for transmittal by' Return re~toi ~//JARuCO Ala~"ka, Inc. / ATTN: J. E. Sallee ANO 954 P.O. Box 100360 Prepared by' J. Zimmerman 700 "G" Street Anchorage, AK 99510-0360 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 SAMPLE TRANSMITTAL TO: Alaska Oil & Gas Conservation Com. 3001 Porcupine Drive Anchorage, Alaska 99501 OPERATOR: AR. CO DATE:4-23-92 AIRBILL #:ALT-511989 AFT#:0-2-4-23-48 CHARGE CODE#19712 NAME: CIRC #1~ SAMPLE TYPE: Dries NUMBER OF BOXES: SAMPLES SENT: ClRC #1 SAMPLES ARE AS FOLLOWS: 100'-2416° (50' SAMPLES WITH THE EXCEPTION OF THE LAST SAMPLE WHICH IS 16') RICK LEVlNSON IS THE ARCO GEOLOGIST 265-1652 SENT BY: Dan Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO AlasKa, Inc. is a Subsidiary of Atlantic Richfieid Company 7ao - / ?.50' - /9~ ,_._,,qo :~o I ! ..9 o -~o _~ ~ o 5"6 I ~ os-o- .? O ¢o ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 April 2O, 1992 Mr. L. C. Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' SUBJECT: Cirque #1 Exploration Well Well Completion Report Request for Confidentiality ARCO Alaska, Inc. as operator of the exploration well Cirque #1, submits the enclosed "Well Completion Report" form 407. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. Attached is the MWD resistivity log, MWD directional survey, and mud log. If ARCO can furnish any further information, contact me at 265-6575. Sincerely, Area Drilling Engineer A. W. McBride J. E. Sallee, ANO-952 Cirque #1 General Wellfile STATE OF ALASKA .... (~ R I 6 iN A [ AL~,XA OIL AND GAS CONSERVATION CO~ .... iSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS [~ SUSPENDED [~ ABANDONED r~ SERVICE [] 2 Name of Operator 7 IPermit Number I ARCO Alaska, Inc I 92-09 & SA 92-061(403) 3 Address 8 APl Number P.O. Box 100360, Anchora~e, AK 99510-0360 50-029-20164 4 Location of well at surface 9 Unit or Lease Name 1015' FNL, 1851' FEL, SEC 20, T9N, R7E, UM ! r: ~::,~,';';~::': ....... At Top Producin§ Interval .: ~ ~,/" NA · - .., CIRQUE#1 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sepal No. WILDCAT RKB 171' ABOVE SEA LEVELI ADL 375076 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completior{s ?~ 02/11./.9~. ?~._ NA .-0314.6t92. ~/'~.1 [~'?.. NA feet MSLI NA 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 2415' MD ,2415' TVD SURFACE YES [~MWD NO O NONE lee{ MD 22 Type Electric or Other Logs Run MWD, MUD LOG 23 CASING, MNER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 218 SX AS I 9-5/8" 36# J-55 SURF 711' 12-1/4' 5200 SX ASII 500 SX AS I TOP JOB 24 Pedorations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET !MD) NA 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED I * See attached operations summary I 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I TEST PERIOD ,e ., Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ ¢..-~ ~' Form 10-407 ¢,,toska 0~! O. ucto Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE Si3E A~C~0-~e~[~ 29. 30. GE(~OGIC MARKERS FORMATION TESTS NNv~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS P & A SCHEMATIC, MWD, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .... _~______~__~ ............ Title AREA DR~ENGI~IEER Date~r~-~~'"- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 2110192 2/11/92 2/12/92 2/13/92 2/14/92 2115192 2/16/92 2117192 2118192 2/19/92 2120192 2121192 2122/92 2/23192 CIRQUE #1 REPORT OF OPERATIONS Move Doyon 14 from Tam # 1 to Cirque # 1. Accept rig at Cirque # 1 at 22:00 hrs on 2/10/92. NU and test dlverter. Spud at 0700 hrs on 2/11/92. Drill from 115' to 1815'. Drill from 1815' to 2415'. Short trip to 1150'. RIH to bottom and circ gas cut mud. Cont circ until good returns with min gas cut. TOH for running 9-5/8" casing. With bit at 765' at 1930 hrs on 2/12/92, well started flowing, unloaded mud on rig floor. Close annular preventer and open dlverter valves, stab TIW valve in attempt to pump mud down drill pipe, pressure up to 3500 psi. Gas cutting out divert lines, shut down and evacuate rig. Gas flow had decreased by 06:00 on 2/13/92 with intermittent flows. Intermittent dry gas flow with some sand, overall flow rate has decreased. Moved Doyon 14 camp to Tam location. RU Dowell pump unit to drill pipe via mud line connection outside of rig. Attempt to kill well with 10.7 ppg CaCl brine. Pumped 7.8 bbls brine and drill pipe pressured up to 3000 psi indicating blockage in drill pipe down hole. Could not unplug drill pipe. Safety Boss personnel on location, begin RU of lines to 2" ball valve below diverter for kill attempt on drill pipe x 16" conductor annulus. Well flow is stronger and wind direction is not optimum for annulus kill attempt. Flow increased at 2300 hrs 2/16/92 with some sand flow. Monitor well flow waiting on wind shift before pumping down annulus. RU 3-1/2".line to relief well pad located 1000' north of Cirque # 1. Moved Dowell pump units from Cirque # 1 pad to relief well pad. Pumped 1253 bbls 11.5 ppg mud down annulus at 2-12 BPM. No noticeable change in gas flow rate out of well during or after pumping. Pumped down annulus again with 1483 bbls of 10.0 ppg mud, SD pumping when full returns observed at surface. No noticeable change in gas flow. Fill hole every 4 hrs. Gas flow rate increasing. Cont to fill hole every 4 hrs. No change in gas flow rate. Plan to repair divert lines. No change in gas flow rate. Removed split divert valve from east divert line. Shut-in east divert line and all gas flow directed out west line. Installed new east divert line. Opened east divert line and SI west divert line. Replaced west divert line and opened same. All gas flow directed away from rig. Flow rate increased at 0230 hrs on 2/24/92. CIRQUE #1 RL, ORT OF OPERATIONS Page 2 2/25/92 2/26/92 2/27/92 2/28/921 2/29/92 3/1/92 312192 313192 314192 3/5/92 3/6/92 3/7/92 3/8/92 Gas flow increasing with dust and sand present. East divert line washed out. SI east divert valve. West line also cutting out. West divert line cut out. Well flowing gas and fine sand. RU Dowell to drill pipe via rig mud lines. Pumped 4.5 bbl CaCL brine down DP when liquid observed in gas flow. SD pumping. Gas and sand decreasing. Monitor well. Begin installing 3" line directly to drill pipe on rig floor. Finished installing 3" line to drill pipe. Pumped down drill pipe with 22 bbl CaC1 brine, 752 bbl 11.4 ppg mud, 86 bbl 10.5 ppg mud and 2279 bbl 10.0 ppg mud at 15-20 BPM. Received returns at surface at 3149 bbls total pumped. Occasional gas flow while pumping, no liquid out of well until solid returns observed. No gas flow after well was filled. Pumped 45 bbl CaC1 brine to freeze protect. Continued monitoring hole and filled hole With CaC1 brine., ave. 0.4 bbl/hr to keep hole full. Filled hole with 6.7 bbls in last 24 hrs. Started clean-up of rig in prep to replace diverter. Cut out old diverter lines. ND diverter stack, cut out damaged diverter spool. Set slips on 5" HWDP on 16" conductor flange. Cut off drill pipe . MU new dlverter, Hang off DP on chains, remove slips, land diverter, set slips on top of of new diverter. RU Dowell lines to fill hole. Installed straight divert lines. Filled hole with CaC1 brine, pumped 103 bbl down DP and 45 bbl down annulus. Re-establish hole fill schedule with 0.7 to 1.0 bbl/hr required to keep hole full. Prep Doyon 14 for moving off Cirque # 1. Fill hole with 16 bbls in last 24 hrs. Thawing/prep rig for move. Fill hole with 13 bbls in last 24 hrs. Moved Doyon 14 off Cirque #1 at 1330 hrs on 3/5/92. Move rig to relief well pad for cleaning/repairs. Fill hole with 7 bbls in last 24 hrs. Scrape pad in prep for Doyon 9 rig move on to Cirque # 1. Move Doyon 9 rig on Cirque # 1, accept rig at 0700 hrs on 317/92. Strip annular preventer over DP stub, stab into drill pipe thru diverter, NU diverter with straight divert lines. Test same. POOH with 17jts HWDP and BHA. Large hole in 3rdjt and small hole in 16th jt. All jts had erosional damage. RIH with 8-1/2" bit to 413', circ out CACL with 10.5 ppg mud. Stage in hole with circulation until bridge at 770'. Circ out gas entrained in mud. Pumped 16.5 bbl balanced Arctic Set I cement plug. POOH and WOC. 319192 3110192 3/11/92 3/12/92 3/13/92 3/14/92 3/15/92 3116192 CIRQUE gl REI'ORT OF OPERATIONS Page 3 RIH with 12-1/4" blt. Tag cement plug at 705', drill out cement to 720'. POOH, RU and run 9-5/8" csg to 711'. Pumped 5200 sxAS II cement with good returns thruout job. No cement returns to surf. Bumped plug to 2000 psi. ND diverter. Pumped 500 ax AS I cement top job. Had 14.6 ppg cement returns at surface. Set slips, NU wellhead, BOPE. Test BOPE with Doug Amos- AOGCC as witness. RU divert lines from BOP stack. RIH with 8-1/2" bit, wt up mud to 11.0 ppg. Test csg to 3000 psi, drill cmt to 691', test csg to 2000 psi Drill out float shoe at 711', drill to 770'. Drilled bridge from 770' to 799'. Lost all returns, pump down drill pipe and annulus a total of 1500 bbls mud and 1000 bbls water before water returns at surface. Keep hole full at 3 BPM while cutting MW to 9.7 ppg. Drilled/cleaned out from 799' to 1601' with circulating after each it. Lost returns below bridge at 1240' but regained quickly. Loss rate at i BPM otherwise, circ out gas cut mud under bridges. Drilled/cleaned out from 1601' to 2125'. Cmt contamination at 2125' from Cirque #1X relief well cement job. Drilled cement from 2125' to 2151'. Verbal approval from Commissioner Lonnie Smith to begin pumping cement plugs at 2151'. Pumped balanced plug # 1 with 300 ax class G cmt w/2% CaC1. POH to 711' and WOC. RIH, tag plug # 1 at 1764'. POOH with bit and RIH with open-ended DP. Pumped balanced plug #2 of 500 ax AS I cement. POH to 698' and WOC. Tag plug #2 at 1306'. Pump balanced plug #3 with 570 sx AS I cement. POH to 443' and WOC. Tag plug #3 at 809'. POOH, RIH with bit and csg scraper to 640', POOH. RIH with EZSV cmt retainer on DP and set at 609', test csg/ret to 900 psi. Est lnj rate of 6 BPM at 450 psi thru ret. Squeezed 500 ax AS I cmt thru ret at 5 BPM at 470 psi and dumped 50 sx ASI cmt on top of retainer. POOH, RIH and set bridge plug at 229'. POOH, LD running tool, RIH open ended, pump 126 sx AS I cement ot top of bridge plug. Good cmt returns observed at surf. ND BOPE, release Doyon 9 from Cirque #1 at 1200 hrs on 3/16/92. Move rig to Cirque #2. 3/21/92 3/22/92 Cut off 16" and 9-5/8" csg strings at 5' below top of tundra. Cmt to top of 9-5/8" and 16" x 9-5/8" annulus. Weld on dry hole marker. Filled hole with gravel around cut-off conductor. Graded pad for final clean-up. Area ~Drilllng Superintendent (cap is 5' below tundra level) cellar'~ cap ,%%%%%%%%%%%%%%%%%%%%%%%%%% ,%%%%%%%%%%%%%%%%%%%%%%%%%% ,%%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% %%%%%%%%%%%%%%%%%%%%%%%%%% ,%%%%%%%%%%%%%%%%%%%%%%%%%% ~%%%%%%%%%%%%%%%%%%%%%%%%%% i%%%%%%%%%%%%%%%%%%%%%%%%%% ,%%%%%%%%%%%%%%%%%%%%%%%%%% ,%%%%%%%%%%%%%%%%%%%%%%%%%% ,%%%%%%%%%%%%%%%%%%%%%%%%%% 809' 1306' 1764' 2151' 2415' ARCO ALASKA, INC Cirque #1 P&A Schematic 3/21/92 All depths RKB unless noted RKB= 35' above ground level 16" conductor at 80' below ground level 9-5/8" bridge plug at 229' RKB w 21 bbls of AS I cement to surface 9.7 ppg mud 9-5/8" cmt retainer @ 609' RKB with 50 sx AS I cement on top to 502' and 83 bbls of ASl cement below. 9-5/8" J-55, 36# BTC csg @ 711' Cemented with 5200 sx (861 bbls) AS II and top job of 500 sx AS I. Plug #3= 94 bbls of Arctic Set I Plug #2= 83 bbls of Arctic Set I Plug #1= 63 bbls of Class G with 2% CaCI2 Cement from Cirque #1X TD of 12-1/4" hole @ 2415' ARCO ALASKA INC. WILDCAT AKMF920208: FEBRUARY 1992 SPERRY-SUN DRILLING SER~.CES, INC. CIRQUE ~1 DOYON 14 NORTH REFERENCE OI IGINAL = TRUE NCET} MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG LE( DEPTH DEGREE DEGREE DEPTH FEET FEET SECTION SEVERIT% -0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0{ 195.54 0.37 234.45 195.54 -0.37 -0.52 0.62 0.!~ 313.63 0.41 259.71 313.63 -0.67 -1.25 1.32 0.i~ 419.04 0.33 238.28 419.03 -0.90 -1.89 1.90 0.i~ 540.99 0.38 259.10 540.98 -1.17 -2.59 2.55 0.I[ 632.04 0.47 323.05 632.03 -0.92 -3.11 2.69 0.5( 722.25 0.31 25.37 722.24 -0.41 -3.23 2.37 0.4' 842.71 0.08 210.26 842.70 -0.19 -3.14 2.14 0.3[ 961.89 0.02 5.94 961.88 -0.09 -3.13 2.06 0.0[ 1080.03 0.51 183.25 1080.02 -0.63 -3.16 2.49 0.41 1184.81 0.45 206.62 1184.79 -1.46 -3.37 3.27 0.Ic 1294.08 0.58 215.95 1294.06 -2.29 -3.88 4.24 0.1~ 1416.92 0.40 201.48 1416.89 -3.18 -4.40 5.26 0.i~ 1541.97 0.36 198.27 154i.94 -3.96 -4.68 6.03 0.0~ 1669.30 0.25 !73.12 1669.27 -4.61 -4.77 6.59 1762.53 0.51 190.00 1762.50 -5.22 -4.82 7.09 0.3~ 1854.41 0.58 193.45 1854.38 -6.07 -5.00 7.86 0.0~ 1980.46 0.47 205.43 1980.42 -7.15 -5.37 8.94 0.]~ 2073.16 0.47 223.56 2073.12 -7.77 -5.80 9.68 0.I~ 2194.35 0.43 224.09 2194.31 -8.46 -6.45 10.63 2288.86 0.42 237.43 2288.82 -8.90 -6.99 11.31 0.i~ 2387.49 0.43 245.73 2387.45 -9.24 -7.63 II.9~ 0.0~ CALCULATIONS BASED ON THE MINIMUM CURVATURE METHOD HORIZONTAL DISPLACEMENT AT A DEPTH OF 2387.5 FEET IS 12.0 FEET ALONG S 39 DEG 32 MIN W RELATIVE TO WELL HEAD VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 219.54 DEG APP ' A DECLINATION OF 28.81 HAS BEEN ':'~~ DEMO -- 5113 09-SEP-91 00:05:54 09-SEP-91 00:06:01 8-***-9] 21:17:32 TO: THRU: MEMORANuUM Sta{e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION / Lonnie C S ~ ;.i' DATE: March 23:1992 Commiss ion~ FILE NO: hh3 2 3- 2. doc Blair Wondzell ~t2a' Sr Petr Eng TELEPHONE NO: SUBJECT: Surface Plug AAI Cirque #1 Permit No. 92-09 Wildcat FROM: Harold R Hawkins Petr Inspector ~~sda¥ Har~ ~ ..... ~99~ When I arrived , AAI had already put the surface plug in. One hundred twenty six sacks 15.7 Arctic set~ bottom of cement plug was 229' up to surface. I took pictures of cement down from surface about 6 feet. Tree will be taken off and marker post put on at a later date. In summary, the Cirque #1 Well is well plugged to surface by AAI Inc, 02-001A (Rev. 6/89) 20/11/MEMOI.PM3 Ab _.~, OIL AND GAS CONSERVATION COMM, ,)N ~ APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon X Suspend Alter casing _ Repair well _ Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging X Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1015' FNL, 1851' FEL, Sec. 20, T9N, R7E, UM 6. Datum elevation (DF or KB) RKB 171' ABOVE SEA LEVEL 7. Unit or Property name N/A 8. Well number CIRQUE #1 At top of productive interval SAME At effective depth SAME At total depth SAME 9. Permit number 92-09 10. APl number 50-1 03-201 64 11. Field/Pool Wildcat 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 0° Surface 6 7 6' Production Liner Perforation depth: N/A measured 2415' 2415' 2415' 2415 Size 16" 9 -5/8" true vertical Tubing (size, grade, and measured depth N/A Packers and SSSV (type and measured depth) N/A feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 218 sx AS I I 15' 1 15' 5200 sxAS II 711' 711' 500 sx AS , top job RECEIVED M AR ?.. 0 1992 Alaska Oil & Gas Cons, Commissle~ Anchorage 13. Attachments Description summary of proposal X Detailed operation program P&A Exploratory well. (Wellbore schematic attached) 14. Estimated date for commencing operation ~ March 7,1992 I 16. If proposal was verbally approved Mr. Lonnie Smith 3/1 3/92 Name of approver Date approved Exploratory X 7. I hereb~y/,.~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~'~-~. ~/~1~~ Title ~ /~//~' S~ ~" / FOR COMMISSION USE ONL'~ J BOP sketch 15. Status of well classification as: Oil __ Gas _ Suspended Service Date ~//~'/~ ~.. I ! Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity m BOP Test m Location clearance __ . I Mechanical Integrity Test Subsequent form require 10- Approved by the order of the Commission ORIGINAL SIGNED BY Commissioner Date Form 10-403 Rev 06/15/88 LONNIE C. Sb,~ITH SUBMIT IN TRIPLICATE P&A Procedure Cirque #1 Note: The information mentioned below is considered to ARCO Alaska, Inc. and it is requested that the Commission all well information concerning Cirque #1. be proprietary by keep confidential No geo-pressured zones were encountered while drilling the well. The surface hole was drilled to 2415' MD with 9.4 ppg mud and the blowout occurred while the drill string was being pulled out of the hole in preparation for running 9-5/8" surface casing. No gas kicks were experienced prior to the trip out of the hole. All significant hydrocarbon zones are covered with cement by the plugging procedure. Current Status 3/18/92 After surface casing point was reached at 2415' on February 12, 1992, a blowout occurred while tripping out of the hole in preparation to run 9-5/8" surface casing. The well continued to flow with intermittent gas rates until the well was killed with mud on February 29, 1992. The damaged rig, Doyon 14, was moved off of the well. Doyon 9 was moved on the well on 3/7/92 to perform the P&A work. The following was the P&A procedure as performed by Doyon 9 and witnessed by Mr. Doug Amos- AOGCC. P&A Procedure 3/7/92 Move in and rig up Doyon 9 on Cirque #1. Pulled 765' of drill pipe and BHA left in well since blowout. 3/8/92 Ran in hole with 8-1/2" bit. Tagged bridge at 770' Pumped 16.5 bbl Arctic Set I cement plug at 770'. RECEIVED MAR 2 0 199~ ,'~laska Oil & Gas Cons. Anchorage 3/9/92 Ran in hole with 12-1/4" bit. Tagged top of cement plug @ 705'. Dressed off plug with 12-1/4" bit to 720'. Ran 9-5/8" casing to 711'. Pumped 5200 sx of Arctic Set II cement (861 bbls) with good returns throughout job but did not observe cement returns at surface. 3/1 0/9 2 Pumped 500 sx Arctic Set I top job (83 bbls) with cement at surface. 3/1 1/9 2 Tested BOPE and drilled out to 770'. 3/12/92 Drilled from 770' to 799'. Lost returns, pumped 1500 bbls of 11.0 ppg mud down drill pipe and 1000 bbls of water down annulus before regaining returns at surface. Decreased mud weight to 9.7 ppg. Drilled/cleaned out from 799' to 2125' by staging in hole one joint at a time with circulating bottoms up between joints. 3/13/92 Encountered cement and contaminated mud at 2125'. Cement was from primary cement job on Cirque #1X relief well. Cleaned out cement/contaminated mud to 2151'. Received verbal approval from Mr. Lonnie Smith to begin setting cement plugs in Cirque #1. Pumped balanced plug #1 consisting of 300 sx Class G cement plug(63 bbls) with bottom at 2151' Cirque #1 P&A Procedure (continued) 3/1 4/92 Tagged plug #1 at 1764'. Pumped plug #2 consisting of 500 sx of Arctic Set I cement (83 bbls). 3/15/92 Tagged plug #2 at 1306'. Pumped plug #3 consisting of 570 sx Arctic Set I (94 bbls). Tagged plug #3 at 809°. Set EZSV cement retainer at 609°. (9-5/8" casing shoe at 711'). Pumped 500 sx (83 bbls) Arctic Set I cement below retainer with squeeze pressure of 470 psi at 5 BPM. Unstung from retainer and dumped 50 sx (8.3 bbl) of AS I cement on top of retainer. Set bridge plug at 229'. Pumped 126 sx (21 bbls) Arctic Set I cement with cement to surface. 3 / 1 6 / 9 2 Rigged down Doyon 9 and moved to Cirque #2. Note: No gyroscopic survey was required as per conversation with Mr Mike Minder on 3/4/92. The MWD directional survey is attached. After rig has moved (Not completed as of 3/18/92) . . . . Dig out, chip out cellar to appx. 4' below tundra level. Cut 16" conductor and 9-5/8" casing at 3' below tundra level. Remove casing stubs, wellhead, etc. and send in for reconditioning. Weld cap across top of 16" conductor. Weld P&A marker post to cap. Top of post is to be from 4' to 6' above original ground level. The following information should be bead welded onto marker post: ARCO Alaska, Inc. ADL-375076 Cirque #1 1015' FNL, 1851' FEL, Sec. 20, T9N, R7E, Umiat NOTE: Notify AOGCC so their representative can inspect marker post. T.A. /18/92 RECEIVED MAR 0 1992 ,Alaska Oil & Gas Cons. ~;ommission Anchorage (cap must be 3' below tundra level) cellar~ cap ::'....::::, ;:'..'.:::.; ::'....::'..~ ;::.'.:::.'. ::'....:::.~ ;:.'.'.:::.: .....-..;:::; ;::..'.:...-:~.; .'..:....':::; ~ ....... ::::...:.-.... ;:::..'::.-. ::::;:::_. ;:::2:.: :::...:::.~ ;:.':.::.'... ::.'.-..'::.., ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::...:::.~ ...... ::"'"'"'::' ~ ..,..,..,..,..,..,..,..,..,..,..,..,..,' 809' 1306' 1764' 2151' 2415' ARCO ALASKA, INC Cirque #1 P&A Schematic All depths RKB unless noted RKB= 35' above ground level 16" conductor at 80' below ground level 9-5/8" bridge plug at 229' with 21 bbls of AS I cement to surface 9.7 ppg mud 9-5/8" cmt retainer @ 609' RKB with 50 sx AS I cement on top to 502' and 83 bbls of ASI cement below. 9-5/8" J-55, 36# BTC csg @ 711' Cemented with 5200 sx (861 bbls) AS II and top job of 500 sx AS I. Plug #3= 94 bbls of Arctic Set I Plug #2= 83 bbls of Arctic Set I Plug #1= 63 bbls of Class G with 2% CaCI2 RECEIVED Cement from Cirque #1X ~AR ~ 0 1992 TD of 12-1/4" hole @ 2415~_laska 0il & Gas Cons. CommissiOn Anchorage ARfO ^~$K INC. WILDCAT AKMF920208: FEBRLIARY 1992 SP-iRR ¥ -£'JN ,~""-' .... NC SEP, V' 2ES, INC. 'ASF. i CZ RQUF. ~1 DOYON 14 NORTH R['F'~R~NCE .-- TR[J~ NORTH MEASURED ~NGL~ DIRECTION VERTICAL LATITUDE DEPTN D~GREE DEGREE DEPTH FEET 0.0C 0,0~ 0.00 ~.00 0.00 195.54 0.37 234.45 195.54 -0.37 313.6~ 0,41 259,71 313.63 -0.67 419.04 0.33 238.)8 419.03 -0.90 540,99 0,38 259,10 ~43.98 -1.17 632.04 0.47 323.05 632.03 -0.92 722.25 0,31 25.37 722.24 --0.41 842.71 0.08 2]0.26 842.70 -0.19 961.89 0,02 5.94 961.88 -0.09 1383.03 0,51 16].25 1080.02 -0.63 1184.81 0,45 206.62 1184.79. -1.46 1294.08 0.58 215,95 1294.06 -2.29 14l&.97 ~,40 901.48 141~.89 -3.18 1541.97 0,36 198.27 1541,94 -3.96 1569.30 0.25 ~73.12 1669.27 -4.61 1762.53 0,51 190,00 1762,50 -5.22 1854.41 0.58 193.45 ~.854.38 -6.07 1989,46 0,47 205.43 1980.42 -7.15 2D73.16 0.47 223.56 2373.12 -7.77 DEPARTURE VERT~CA[. DOC LEG FEET SECTION SIVERITY 0.00 0.C0 0.30 -0.52 C.62 3.19 -1.25 1.32 0.15 -1.89 ]..g0 3.15 -2.59 2.~5 0.11 -3.11 2..69 0.50 -3.23 Z,37 0.47 -3.14 2.}4 0.32 -3.13 2.06 0.05 -3.16 2,49 0.41 -3.37 3 · 27 0 . 19 -3.88 4 . 24 0.14 -4.40 5. 26 0.17 -4.68 6.02 0.04 -4.7? 6.5g 0.13 -4.82 7.09 0.30 -5.00 7.~6 0.08 -5.37 8.94 0.1.2 -5.80 9.68 0.16 2194.35 0.43 224.09 2194.31 -8.46 -6.45 2288.86 0,42 237.43 2288.82 -8.90 -6.99 2387.49 0.43 245.73 2387.45 -9.24 -7.63 CA£CULATIONS BASED ON THE MINIMUM CURVATURE METHOD 10.63 0.03 1] .3l 0.10 11..9~ 0.06 HORIZONTAL DISPLACEMENT AT A DEPTH OF 2387.5 FEET ~S 12.0 FEET ALONG S 39 DEG 32 MIN W RELATIVE TO WELL NEAD VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED aLONO 219.54 DEG A DECLINATION OF 28.81 EAS B~EN APPLIED 5113 09-SEP-91 00:05:54 09-SEP-91 00:06:01 9] 2I:'7:32 R CElVED MAR ?_ 0 t992 Oil & Gas Cons. Commission Anchorage ' AOGCC GEOLOGICAL MATERIALS INVENTORY UST " i check off or list~lata as it is received ~ 407 ! ~/~/~ drilling histo~~' su~ey .~. tests ! ~= "esripti,°nl cored i~tewals ~re anai~is d~ dit~ intewals digital data , I ,I , , LOG TYPE RUN INTERVALS SCALE NO. ,, 1i]' " ,, 12] 13] ,, 14! 15! ............ 1 7] ...... 1 ~] TO: THRU: FROM: MEMORANuUM State of Alaska O~ AND GAS CONSERVATION COMNISSION ALASKA Lonnie C. Sm" Commissione Blair Wondzell Sr. Petroleum Engineer Doug Amos ~~ Petroleum Inspector DATE: March 20,].992 FILE NO: DA. 32092-1 TELEPHONE NO: SUBJECT: BOPE Test~l~,]©~ AAI Cirque #1 Permit No. 92-09 Exploratory Sec.20,T9N,R7E,UM :Tuesda~y March 9, 1992:_ I traveled this date from my residence to Prudhoe Bay and on to AAI's Cirque No. 1 exploratory well to stand by for the BOPE test on Doyon Rig No. 9. Wednesda March.10_10_~l1992: Due to ~the additional work required to add two 4 1/2" vent lines below the BOPE stack, the BOPE test was delayed. Thu~d~_y__=qarch 11__~_1992: The testing commenced this date at 1:30 am and was concluded at 6:45 am. As the attached AOGCC BOPE inspection report indicates the gas detectors required calibration, which was completed before drilling out the 9 5/8" csg shoe. ~ March 12 199~: I witnessed the 9 5/8" csg shoe test this date. The shoe was tested with 1900 psi, the pressure dropped to 1800 psi after the first 15 minutes of thc test and remained constant for the remainder of the 30 min. test. At 1900 psi additional weight was required on the casing to restrain it's movement. In summary, I witnessed the BOPE test at AAI's Cirque #1 exploratory well on Doyon Rig No.9. The gas detectors required calibration, which was completed before the csg shoe was drilled out. I also witnessed the successful 9 5/8" csg shoe test Attachment. ~'C, ONFIDENTIA~ ~ ~I~ 31.05.035 , · 02-00lA (Rev. 6/89) 20/IUMEMO1.PM3 OPERATION: Drlg Operator STATE OF ALASKA ALASKA O ! L AND GAS CONSERVAT l ON COMM ! SS I ON BOP Test Report Wkvr TEST: Initial Representative Permit # Location: Sec ~ T ~AJ R ~ M Location (general) ~ Well sign Housekeeping (general) ~ Rig Reserve pit ~ Rig# MUD SYSTEMS: Vi sual Audio Trip tank gauge Pit Flow monitor Gas detectors ,.~ ~' BOPE STACK: Test Pressure Annular preventer P i per ams c' l,~ ~;.- , Blind ramso~ Cho e I HCR valve ~ v' ~ / Kill ]ine valves ~/~ tl t/ II Check valve ~ I 1, /1! // Casing set @ -7// ! ft Rep ACCUMULATOR SYSTEM: Full charge pressure Press after closure ~,, /(~ psig / ~7~0 psig Pump incr clos press 200 psig rain ~ sec Full charge press attained ~ min ~ ! sec Controls: Master Remote B1 i nd switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly / Test pressure Lower Kelly /'i Test pressure Ball type ~h' j Test pressure Inside BOP Test pressure Choke manifold ~/ Test pressure Number val yes ~' ~ ~ Number flanges ~ ~j Adjustable chokes Hydraulically operated choke Failures / Test time ...... hfs Repair or replacement of failed equipment to be made within days. Notify the Inspector, and follow with written/FAXed verification to Commission office. TEST RESULTS: ._~ ! D~stribution: J STATE WITNESS REQUIRED? J Waived by: J yes/ no J J 24-HR NOTICE GI~N? I ! -yes/ no j orig - AOGCC c - Operator c - Supervisor Witnessed by: MEMORANDUM Sta e of Alaska ALASKA OIL AND GAS C~DNSERVATION COMMISSION TO: Lonnie C. ........... £ommissionerf/-~ THRU: Blair Wondzell sr. Petroleum Engineer FROM: Petroleum Inspector DATE: FILE NO: TELEPHONE NO: SUBJECT: March 10,1992 DA.31092 Well Blowout, ~Y°~ AAI Cirque ~1 Well Permit No. 92-09 Exploratory Sec.20,T9N,R7E,UM. ~sda¥ Feb _12,1992.:~ I was contacted by phone at 11:00 pm by commissioner Lonnie Smith and informed that while POH to run 9 5/8" csg, Doyon Rig No.14 at AAI Cirque No. 1 exploratory well encountered a gas kick and had to divert the flow. The rig and camp were then evacuated due to gas, mud and gravel flowing from the wellbore. Thur. MdD_y__~eb. ~3~19~21~ I traveled this date from my residence to Kuparuk Rv. field, via an AAI charter flight and then on to the Cirque well location, south of 2M pad. Upon arrival at the Nordic Rig No. 1 camp~ placed 2 miles from the Cirque Well pads and designated as the command center~ I was briefed by Doug Sholts, AAI Drilling Superintendent and given the following information. While drilling the 12 1/4" hole for the 9 5/8" csg~ gas had been encountered. The mud weight had been raised, from~9.2 to 9.4 ppg and the gas circulated out of the hole. The hole was drilled to 2500'~ setting depth of the 9 5/8" csg. After a short wiper trip, John Rall AAI rep made the decision to POH and run csg. At approximately 8:30 pm and at a depth 855' the well began to unload mud~ gravel and gas onto the rig floor. Mark Egholm Doyon toolpusher was notified by the driller of the condition and proceeded from the camp to the rig floor. Mark immediately closed the diverter and opened both divert valves. Approximately~10 minutes later he evacuated all personnel. from the rig floor and shut the rig power down. As shown in the video'~ taken by me on this date~ both diverter lines washed out downstream of the divert valves ~elow the_.tar~eted te~'s where they exit the rig substructure. Due to wind direction, camp placement and gas blowing from the wellbore the camp was also evacuated. The well flowed gravel and mud for about 30 minutes and then approximately 30 to 40 mmcf of dry gas and sand for another 02-00lA (Rev. 6/89) 20/11PMEMO1.PM3 "hours at whJ time ~t subsided to 2 t, ..... ~.. mmc'.f c~f dry gas~ i arrived dt the well location at.,~'.. pm and took video f'ootage ~ th ,_~ e east side wash out Tile flew from hhe we~l remained at I to 2 of ~- to t0 ~mcf for th~ rema2nder of Chi.~ dat. e A~ter Arco and Doyen personnel inspect, ed the r~g mud pump rooli~ decisioil was made to rig up DeweLl pu~ping units and ~ ~'~ ~' 5nn bbi tanks and at, tempt to kill the well with in 7 brine by pumping down the dr~L], pipe through a cennect:i..on ~ade at the rig mud pumps. Fri~Feb. 14_j_~39%~2~:. The flow from the well remained at 1 to 5 mmcf. Dowe].l was rigged up on the location and after' cooling the brine to approximately 60 degree's pumping ~omm~,aceu at,:~.:un,~ pm ........... s were pumped ('~... bbl's to fill the lines) before encountering a plug in the drill[)ipe. Arrangements were made te start construction ef the relief well. ice pad 1400~ NW of the existing weli, also to import from Canada~ Safety Bess Well control specialists, Deyou Rig No. 9 was selected to drill, the relief well· and moving commenced from DS-15 in Prudhoe Bay at midnight. SatuK~~i992: The flow from the wellbore at 1 to 2 mmcf unt~ . · ~1. around 1:00 pm and then subsided to 500 mcr with no surging, The Safety Boss specialists~ Ken Rose and Jarvis Jacksol~ arrived on iecatien at t0:30 am. They entered the rig . t~ - ~ .... ~.~, l~q a substructure te access ~ damages ~o the ,~a~' _ 'head nd diverter equipment and found the diverter, divert valves and annulus valve te be in good condition and functional, when thawed and opened the annulus valve flowed mud. Decision was made te hook up Dowell te the a[~nulus valve and attempt te pump down the annulus to kill t'he well. Due to wind direction change, btewi~g from the SE, gas from the well. bore was blowilig toward the pumping units thereffore operations had to be suspe~ded~ sunday_ Feb. 16_,_=_~992: The flow from the we!lbore remained at 500 mcf to ...... 1 mmcf of dry gas and occasional ~-~n,.~ ''~ ~ The wind direction held from the SE, which kept pumping operations suspended~ Construction of the relief well pad was onqoing and completioll was ex~0ected ear'ly 2/1° '~2 Decision was made to pump 11~5 ppg m~ld in place of bvi~e to minimize further damage te the wel!bore~ also to relooate the Dowell pumping units and tanks to the relief well. pad, ~. allow Dumping te continue unencumbered bv the wi. nd direction, Safety Bess specialists installed AAI fire department spray monitors in front, of the substruct~z-e doers~ enabling water er foam to be directed onto the wellbore, in case of ignition of the gas. Monda-~ ~, 1992: The =' ~,~:m.~l,_d at ~.~ow fr,o~ the wel!bore ~ ='"~ 500 mcr and below. The constructJ, o~ of the relie~ well ].ce pad and drilling of tilec.~ondtk..tor- ~ ~ ..... was comp].e't'~d late in the evening this da' ' and Dowe-il commenced mov~ onto the ...... b.ul's of In location The )0 bb] ~s o~ 1t 5 ppg and 0 '-~" .,.~ ppg mud was in the process of being ~ixed a,~ Parker' Rig No. 245 on 30 pad -~= ~ a~ at Audi No. 3 mud plant staged at 2H pad. ~Y____D~-~ 18.__. 1992: The flow from the wellbore increased to approximately 5 mmcf in the early morning l'~our's blowing dry gas only~ The Dowell p~.lmping units and tanks were relocated and hooked up to the 1400 ft. of 3 1/2TM tubing tied into the annulus valve~ but mud volumes on location were not sufficient to begin pumping operations. W~~da,~ Feb.~i%_~ 1992: The flow from the wellbore subsided to appro×imatety 2 mmcf. Pumping commenced at. !1:30. .--.. am with 10,~-~ ~' .... ppg mud at a 5 bbl/min rate at ,.~.~30 psi~ p%~mping efficiency was estimated at 35%. The pump rate was steadily increased to rate of t2.5 bbl/min at 840 psi. After pumping 1450 bbl's of the 10~2 ppg mud the pumps were shut down and the fluid flow from the wellbore stopped almost instantaneously, However the well ,.~t~.ll ~ ~ flow~d approximately 5 mmcf of dry gas. Pumping was s~spended until 4:30 pm and resumed with 11~5 ppg mud. The well took 22 bbl~s of mud before full returns were received at surface, A four hour pumping schedule was established wlt'h the well taking 12 too 14 bbl's of mud at each pumping interval ~ ~rsda_l_Feb. 20. 1992: The flow from 'the weltbore increased to I0 mmcf for the remainder of this date. Pumping was continued at 6 hour intervals with the well taking the same 12 to 14 bbl's of mud at each interva]~ Dc, yon Rig 1..~o. 9 reached the relief well pad early in the morning and up operations commenced~ I approved the diverter desig'n with two straight 10 3/~" vent lines, orientated I80 degrees fro~ one another~ Two I0' full opening ball type valves were used instead of the knife type divert, er valves used on Doyen Rig No, 14, ,Friday. :F~eb. 2!_~b___1_~92~, I departed the location early t..his d .... r,o ~ondu~t~ The fl~,~,; from ~t~:~ before the diverter ~ .... ~t was c. the we' ~' o-~ ~--~' ~- llb~e was at a ~2~h~5~nt lO mmcf of dry gas at my departure. In summary~ i observed and collected information on the AAI .... ~..~ ~ 1 explc, ratory well blowout, From the information I gathered the well was properly filled while POH to r~n csg and the mud weight had been increased to overcome the gas influx into the weilbore while drilling the hole. appears that swabbing of the hole while tripping out for the csg run played a major role in taking the gas {{'.J. ck. Loss of control of the well can be attr ........ :v ih,,+-~ to th~, diverter line washouts in and around the rig st.lhstructure, requiring ~.omp~.~te shutdown and ~vacuation of th_e r'ig~ Temperatures of -50 degreeD 'ompounded the problems a.~-' ciated with the ~htltdown by fr~: ~zing the rig pumping unit~ nd mud ].ines. making it impossible to use the rig equipment to kill the weii~ Th~oughout my 9 day stay at the location, A~-co personnel were very cooperative and kept me informed of all procedures in use, Arco fire fightfng~ emergency medical team~ and equipment were on location within two hours after the blowout occurred and were maintained on alert status 24 hours a day until the well bridged its self off~ Well control specialists were imported from Canada once lnitia! attempts to kill the well through the drill pipe failed~ It is my opinion that all possible precautions and kill procedures were taken by Arco during this blowout and that this resulted in the minimal damage to the envi~-'onment as well as the lack of injure to all personnel. ARCO Alaska, Inc. Kuparuk Opera.ons Post Office Box 196105 Anchorage, Alaska 99519 Telephone 907 659 2821 March 4, 1992 · Certified Mail Return Receipt Requested P 580 5O3 830 Bob Cannone Alaska Department of Environmental Conservation Northern Region Office 1001 Noble Street, Suite 350 Fairbanks, Alaska 99701 Re: Cirque #1 Exploration Well- Blowout Event i;tECEIVED M R- 9 1992 Dear Bob' Alaska 0il & Gas Cons. C0mmis¢O'n Anchorage The purpose of this letter is to advise ADEC of the extent of discharges incurred during the captioned event and to further advise you of cleanup plans. As you are aware, ARCO Alaska Inc. (ARCO) and ADEC have already, jointly visited the wellsite and discussed discharge contents, volumes, and cleanup plans. We would appreciate a response to the following action plan. On February 13, 1992, ARCO Alaska Inc. (AAI) notified ADEC that during exploration drilling operations, a shallow high pressure gas pocket was encountered causing a dry gas blowout. During well kill procedures approximately 2,062 barrels of fresh water based drilling mud and 20 barrels of brine were vented out the well. The majority of the mud and all of the brine was expelled to the surrounding ice pad, and a smaller amount of drilling mud reached the snow covered tundra. In addition, prevailing winds carried fine formation sands and quartz intermittently over an area within a 1.5 mile radius from Cirque well site, dusting the snow with particulates in varying depths. See attachments for an overview of the areas affected by the blowout. The well has been killed and once the drilling rig is secured and removed, 100% clean-up of the ice pad is expected. The snow heavily covered with drilling mud (1/2" or greater) off the ice pad will also be removed. Any mud directly on the tundra will only be removed to within a 1/2" of the tundra to prevent unnecessary damage to the vegetative mat. Preliminary consultation with Torre Jorgenson of Alaska Biological research, Inc. (ABR) confirms that minimal impact is expected using this cleanup threshold. Vascular vegetation can withstand loading of gravel 2" thick, similar resiliency is anticipated for the areas of medium and light dusting. While some moss could be temporarily smothered, this one time episodic event should pose minimal problems. No clean-up procedures will take place for dusted areas unless several inches are determined to be at a particular location. Strong wind continue to promote redistribution of the fine particulates over a larger ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Bob Cannone March 4, 1992 Page #2 Re: Cirque #1 Exploration Well- Blowout Event area and, an average snow cover of 6"-12" plus spring accumulation are expected to flush these areas naturally and leave little if any cosmetic- evidence. Following the spring thaw and breakup period, consultant services will be secured to assist in conducting an aerial inspection of the area. A closer visual field inspection of the areas that had the most significant deposits; as well as any areas of concern noted from the aerial inspection, is also planned. Should any signs of stress or tundra damaged be observed, a remediation plan will be developed and implemented. If you have any questions regarding this plan, please contaot Willie Willenbrink or me at 659-7866. We look forward to your response. Sincerely, Associate Environmental Coordinator Attachments cc; Bob Flynn, ADEC Mehrdad Nadem, ADEC Rick Smith, DNR Ralph Davis, NSB Blair Wondzell, AOGCC 230/013.2/mjk Cirque Sampling Plan Preliminary sampling is being performed to help characterize the particulates that were deposited on the snow from the Cirque Exploratory Well blowout. Samples will be tested to determine the presence of drilling mud, formation sands, brine, and hydrocarbons. Initial delineation of the extent of mud and formation sand, and the various depths of deposition will be performed by Lounsbury & Associates surveyors and mapped out from visual observations. Once particulate distribution has been surveyed and categorized (heavy, medium, light) two (2) samples will be taken from each area. One should be from an area with heavy deposition, and another more representative of the average deposition. Analysis performed based on the knowledge of the potential particulates to be expelled during a blowout will correspond to KRU reserve pit leachate monitoring program. Detection limits will be the same as those specified in the Alaska drinking water standards. Due to the large area and the visual homogeneity between dusted areas, this will allow us to extrapolate from the data the area of concern. · Safety: You must check in at the incident command post where you must participate in a safety meeting before being allowed on site. These rules must be followed at all times. If safety concerns prevent acquiring a sample representative of the program, note reason and any deviations from the plan taken. Never compromise safety. · Six (6) discrete samples are to be taken, two (2)-from each of the designated areas: heavy, medium; light. The samples analyzed for the full set of parameters will be taken from the heavily dusted spot within each designated area. The remaining only need TPH and salinity analysis. The second sample from the designated area will be representative of the level of dusting within the area. · Measure depth of snow at each Sample location. · Keep volume of snow sampled consistent between each sample location. · Sample from the lightly dusted area to the heaviest, to prevent cross contamination. · Take one control sample of clean snow · Take one field duplicate. · Write corresponding sample numbers on jars, chain of custody form, map, and lathe used to mark sample location. · Take thorough log notes: Must be consistent w/ ARCO Kuparuk sampling expectations/S OP's. · If at anytime there are questions call the Field Environmental Office 7866 or pager 189-669 RECEIVED 230/013.1/mjk 3/4/92 MAR - 9 1992 Alaska Oil & Gas Cons. Oommissio[~ Anchorage Cirque Exploration Blowoul Affected Snow Analysis All values In mg/L unless noted Sample TPH Salinity Barium Chloride Chromium .Cadmium Lead Sodium Zinc Potassium Aluminlum Areani¢ Mercury Sulfa#si iPolnt ~ 22'C · ~C~ntrol <0.5 <.2PI~ <0.5 6.4 <0.002 <0.001 <.002 3 <0.0~ <0.1 <0.2 <0.005 <.0005 0.9 <.2pp~ 12 12 0.58 0.013 0.32 60 1.6 36 7.2 · 0.13 <.001 28 <.2ppi 37 5.5 0.12 0.002 0.076 13 0.3 8 35 0,073 <.0005 7.4 <.21~ 2 1 1 0.21 0.006 0.207 30 0.8 18 84 0.109 <.0005 21 <.2t~t 12 2.5 0.02 0.002 0.01 3 0.1 1.6 7 0.01S <.0005 2.6 #1 1.5 #2 3.5 #3 1.5 #3 FD' 0.5 14 I #$ 2.6 #8 <0.S 'Field Duplicate Nme: The data reflecle~ hera is baaed on ~x~nlrallon measured in m~ted .now. Elfectiva c~x~ent~alions In standing wate~ wo~ld be elgniflcamly Iowe~ Ihan Indicated and i~olxxlionat Io the amount of ~now depth and lUHaCl runoff. kCIRQUERELIEF WELLi CIRQUE, HEAVY MEDIUM LIGHT 194,709 sq. ft. 4.4 acres ii REVISION DRAWN: .... MO SCALE: 1"=500' ......... DEIGN: APPROVAL: DA]E= 282,278 sq. ft. 6.4 acres 3,276,724 sq. ft. 75.2 acres ~ AS-BULT LOGA'IION Y,-S.me.224 lO18' F. It,L~ 1,a81' F~ WEllS VIC/N/TY MAP s:o/.. ~'~ SAMPLE LOCATIONS i ! ii FCR NO:. XF~/CC KM4218 CADO RL~ NO. ] LKDOC745 J 2/23/92 IIII I Ir - · NOTES L BASIS ~ HORIZONTAL LOC4TION IS MONUIIBVT "0-1" AND MONUMBVT DS 2-14 SOUTH PER' LOUNS~IJRY ~ AS~ATE~ E. COOROINATE~ SHOMV ARE ALASKA STATE PLANE ZONE 4, ALA. D. 2X 3. DELTA ALPHA ,4 T CIRQUE RETJEF WELL IS -00' 23' 03.452". 4. IMPACTED AREAS ARE OETqNED ,AS FOLLOIV~: HEAVY- P~ OF* I/2' OR GREATER MUD MEOIUM - POCKE~ OF I//8. ~0 1/~2° MUD UONT- AREAS OF OUST AND IMMEASURABI.~ PEBBLE TYPE MA TE~/AL, I/4' TO I I/4' DIA. · i J i i i i iiii , ARO0 Alaska, Inc. ~'i' ORQU£ ~K WELL BLOWOUT Subsidiary of Atlantic Richfield Company I IMPACTED AREA i. ,o= oc.# I .......... 92 ,:9]~ ............ - ........ · ~ LOUNSBURY ........ D.S.2M \_CIRQUE REUE~: WELL CIRQUE 1X- ~ ClD_LAR AS-BUILT LOCATION ~ . ' . ' ' '~I[ X- 4~9,121 /. . ' . · - . ' . ' ~'~1'I~ LAT-.70' 07' 38.05' / - · . . ' · . . . ',,,1 ~ LONe,,-150' 24' .31.05' /. ' - - . ' . ' · . . ,% I I ~'~...L..~.~'F.u_ /. ' .' _ · · .'. · · . -'l SEC. 20, T g N, R 7 E : . · " p....:.'...L .../:~ -'..' .' :¢;. :. '..: · "-.'~' :::::::::::::::~"'" o~' SAMPLE LOCATIONS DRAWN: DESIGN: FCR NO: MO - - ARO0 AlImka, Ino. CHECKED: ~/~ AP, PROVAL: AFE/CC NO: - - KM4218 Subsidiary of Atlantic Richfield Compciny SCALE DATE: CADD FILE NO. JOB NO: SUB JOB NO: DRAWINO NO: REVISION I NONE 3/04/92 LKDOC753 92-015 - WELLS VICINITY MAP $ccle:? '-- ,,~ ~1. .NOTES 1. BA515 OF HORIZONTAL LOCAT/ON IS MONUME~IT "0-.1" AND MONUMENT DE 2-M EOUTI-I PER LOUNS~URY ~. ASS'OCIA TE~. 2. COORDINATE~ 51'/Oit/N ARE ALAS)~4 ETA TE PLANE ZONE .~, N, AD, 27. 3. DELTA ALPHA AT CIRQUE RELIEF WELL /I, IPAClED AREAS ARE APPRO)Et, IA TE AND WERE DERNED BY REVIEW OF FLIONT PHOTOi~APHY TAKEN FEBRUARY 26, 1992 AND BY ~ROUND INSPECTION ON MARC/'/ 1, 199Z IMPACTED ARE/IS ARE CONTINUAZI. Y REDE~"/NED BY ~ND SCA TTEREI) PARTICULA ~E. DOC. .~.~,,,.,~' LOUNSBURY & .~3~~, ]:1~'C. CIRQUE WELL BLOWOUT REDEFINED IMPACTED AREAS AS OF 3/01/9 J PAC~: REV: lOrl ARCO Alaska, Inc. Kuparuk River Field Sample Chain of Custody Environmental Related Sampling Laboratory Sent To: KIC' RECEIVED Attn' Steven Rae Send Report To: Attn: Cathe Grosshandler Kuparuk Environmental NSK 61 Chg. Code: KM4218 Lab Collector's Sample Sample Date & Sampled Sample # Sample # Location Description Time By !~.Y,t'3~, o / Cirque Exploration Snow contaminated w/ ~. 77.~ ,,~-~..~-- ? ~ Well Drillin~ muds Requestor' NSK Environmental Name of Field Environmental Compliance personnel consulted' Cathe Grosshandler Analysis Requested: 3_ centerline samples: Salinity Total Petroleum Hydrocarbons IR SM 503E Total Metals {'EPA method): Barium (method 208.2); Chloride (method 300.0); Chromium (method 218.2); Cadmium (213.3); lead (239.2); Sodium (273.1); Zinc (289.1) Potassium (258.1); Aluminum (202.1); Arsenic (206.2); Mercury (245.1); Sulfate (300.0) All Other Samples: TPH and Salinity only. Chain of Custody Record: Relinquished by /,.~,~.,, ~-'~ Received by: · · ,' /' ~' ~" 7 Rehnqmshed byL Received byL Title: -;.~ '¢. Date: .¢/., ~":',.. ~'' Time' '/5 Title' ~ ....: Date: :' ';;':~>'-- Time' Title:.~~c~ Date:}-2:~ Time' /3.~ Title: x-,~ ~-.; ~7' Date:; "-?~ Time' ,,' bcc: 1 copy to lab, 1 copy to sampler, and 1 copy to requestor upon receipt of sample Env Sample Form Oct 91 K1C LAB QA/QC REPORT Q0292039 :.:............... :.: :.:.-..-......... :..:.:.:.:.:.:.:.:.:...............:.....................:.:.:.:.:.:.:.:.:,:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.: :.:.:.:.-........ ..... .:.:.: .:.:.:.:,:.:.:.:.:.:.:.:.:.:.:.:.:.:.: :.:.: ........-...: ........:.:,: :.:.:.:......,,,,>,::,::.:. :,,,,,,,:: :::: ·., · .:~,:: .:,:.S]amp~,-..... ,......:..$.amp.~... ........ : .:.:.:.:.:.:.:.:, Samp!eO.es. ~3r. ipt!on:.:.:.:.:.:.:.:.:..:.......:.:.-.....:.-...... ............ :.:.:..:....A~L.¥. :~. D.-.-................. :.:.:.:.:.-.....-.-.. .... :...-.:.... :.:.:.:.:-.:.:.Guwe.....C.'OT.~!.:.: .:.:.:%'ReC.O.......ye.fy:.:..:.:..%.'Rec.o.v.e,ry:.:. ~~*.:::.: ~ ~ ~ SALINITY 0'2,/23/92 <0.2 ppt n/a 98.6% Sampled 2/22/92 1 31 0 hr 41 8.1 by RWN T. Petroleum 02/23/92 < 0.5 rog/l_ 0,999 91.6% Hydrocarbons COMMENTS: ARSENIC 02/24/92 < 0.005 mg/L 0.999 105.9% All method blanks < MDL BARIUM 02/24/92 < 0.5 mg/L 0.999 1 00.0% -- Unfiltered samples were CADMIUM 02/24/92 .. <0.001 mg/L ... 0.990 1 2P_9% acid digested for Total CHROMIUM 02/24/92 < O. 002 mg/L 0,999 81.6% , Recoverable Metals 0'2/23/92. LEAD 02/24/92 < 0.002 mg/L 0,999 1 09.3% MERCURY 02/24/92 < 0.001 mg/L 0,999 1 02,0% · RPD Relative Percent Difference SODIUM 02/24/92 3 mg/L 0.999 1 03.0% D1 = 1 st Result D1 -D2 POTASSIUM 02/24/92 <0.1 mg/L 0.999 D2= 2nd Resull ................ X1 O0 ZINC 02/24/92 <0.05 mg/L 0.999 1 04.4% (D1 +D2/2) ALUMINUM 02/24/92 <0.2 mg/L 0.992 85.0% CHLORIDE 02/23/92 6.4 mg/L O. 999 SULFATE 02/23/92 O. 9 mg/L O. 999 .,~ ~~~'~..~, S.J.Barnsley/Stephen Rae KIC LAB Manager KIC LAB QA/QC REPORT Q0292039 __ 92020092 9202062 ~ SALINITY 02/23/92 <0.2 ppt n/a 98.6% Sampled 2/22/92 1 21 0 hr 41 8,1 by RWN ; T, Petroleum 02/23/92 1,5 mg/L 0,999 91,6% Snow Depth 7,5" Hydrocarbons COMMENTS: ARSENIC 02/24/92 O, 073 mg/L O, 999 1 05,9% "~"~ / All method blanks < MDL BARIUM 02/24/92 37 mg/L 0,999 1 00,0% - Unfiltered samples were CADMIUM 02/24/92 0,002 mg/L 0,990 1 22,9% acid digested for Total CHROMIUM 02/24/92 i 0.1 20 mg/L 0.999 81,6% Recoverable Metals 02/23/92, LEAD 02/24/92 0,076 mg/L 0.999 1 09,3% MERCURY 02/24/92 <0.001 mg/L' 0.999 1 02,0% 1 02% * RPD Relative Percent Difference soDIuM 02/24/92 1 3 mg/L 0,999 1 03,0% D1 = I st Result D1 -D2 PoTASsIUM 02/24/92 8 mg/L 0,999 D2= 2nd Result X1 O0 ZINC 02/24/92 0,3 mg/L 0,999 1 04,4% (D1 +D2/2) ALUMINUM 02/24/92 · 35 mg/L 0.992 85,0% ,,, CHLORIDE 02/23/92 5,5 mg/L 0,999 .... SULFATE 02/23/92 7.4 mg/L O. 999 92O20093 9202053 SALINITY Sampled 2/22/92 1 200 hr 41 8.1 by RWN T. Petroleum Snow Depth 9.5" Hydrocarbons 02/23/92 02/33/92 <0.2 ppt 1 .o mg/L :: ::: :instrument:::: :i: :QA: cI-iec.k, i std:i~ n/a 98,6% 0.999 91,6% COMMENTS: All method blanks < MDL 02/28192 S.J.Barnsley/Stephen Rue KIC LAB Manager KIC LAB QA/QC REPORT Q0292039 9202(X)90 9'20'2050 ~ SAUNITY 02/23/92 <0.2 ppt n/a 98.6% Sampled 2/22/92 1 1 33 hr 41 8.1 by RWN T. Petroleum 02/23/92 1.5 mg/L O. 999 91.6% Snow Depth 6. 5" Hydrocarbons COMMENTS: ARSENIC 02/24/92 O. 1 30 mg/L O. 999 1 05.9% All method blanks < MDL BARIUM 02/24/92 1 2 mg/1.. 0.999 100.0% 81% Unfiltered samples were CADMIUM 02~24/'92 0.01 3 mg/L 0.990 i 22.9% 8.0~ acid digested for Total CHROMIUM 02/24/92 0.580 mg/L 0.999 81.6% 3.4% ,,, Recoverable Metals 02/23/92. LEAD 02/24/92 O. 3,°0 mg/l_ O. 999 1 09.3% O. 0% MERCURy 02/24/92 ' . '<0.001 mg/L 0.999 102.0% " * RPD Relative Percent Difference SODIUM 02/24/92 60 mg/L 0.999 1 03.0% i 5.4% D1 ,= 1 st Result D1 -D2 POTASSIUM .... 02/24/92 36.. mg/L 0.999 .. 0.0% D2 = 2nd Result -X1 O0 ZINC 02/24/92 1.6 mg/L O. 999 1 04.4% 0.0% , (D1 +D2/2) ALUMINUM 02/24/92 72 mg/L 0.992 85.0% 0.0% CHLORIDE 02/23/92 1 2 mg/L O. 999 SULFATE 02/23/92 28 mg/L O. 999 KIC LAB .Samp#. 9'20'2(X)91 ARCO KLI CIRQUE WELL Snow co,e I' .'ANALYTE. 9202051 ,.,~_ ~_ .'I._~ ~ SALINITY I~y HV'V_N .. ~T. Petroleum Hydroc3rbons COMMENTS: All method blanks < MDL 02/23/92 O2/23/92 RESULT . . <0.2 ppi 3.5 mg/L Inshument Curve Corr. n/a 0.999 QA cl]eck SId. %RecoVerY 98.6% 91.6% Matrix SPike!' %ReoOverY. SPlit sample:!:!: .i ii .::' RpD ,ti!iiiii! 02/28/92 S.J. Barnsley/Slephen Rae KIC LAB Manager KIC LAB QA/QC REPORT Q0292039 92020097 9202057 ~ SALINITY 02/23/92 <0.2 ppt n/a 98.6% Sampled 2/22/92 1 31 0 hr 41 8.1 by RWN T. Petroleum 02/23/92 0.$ mg/L 0.999 91.6% Snow Depth 7.5" Hydrocarbons COMMENTS: 'ARSENIC 02/24/92 0.1 09 mg/L 0.999 1 05.9% 1 26.00/o All method blanks < MDL BARIUM 02/24/92 2 mg/L 0.999 1 00.0% Unfiltered samples were CADMIUM 02/24/92 0,006 mg/L 0.990 1 22.9% acid digested for Total CHROMIUM 02/24/92 0.21 0 mg/L 0.999 81.6% 96.0% Recoverable Metals 02/23/92. LEAD 02/24/92 O. 207 mg/L 0.999 1 09.3% 1 1 8.0% MERCURY 02/24/92 < 0.001 mg/L 0.999 1 02.0% 1 02.0% * RPD Relative Percent Di~erence SODIUM 02/24/92 30 mg/L 0.999 103.0% D1 = I st Result D1 -D2 POTASSIUM 02/24/92 1 8 mg/L 0.999 D2= 2nd Result ............... X1 O0 ZINC 02/24/92 0.8 mg/L 0.999 1 04.4% (D1 +D2/2) ALUMINUM 02/24/92 84 mg/L 0.992 86.0% CHLORIDE 02/23/92 1 1 mg/L 0.999 SULFATE 02/23/92 21 mg/L 0.999 O2/28/92 S.J.Barnsley/Stephen Rae KIC LAB Manager KIC LAB QA/QC REPORT Q0292039 9202(X)95 92020~ ~ SAUNITY 02/2~92 <0.2 ppt n/a 98.6% Sampled 2/22/92 1240 hr 418.1 by RWN T. Petroleurn 02/23/92 < 0. 5 mg/L 0,999 91.6% Snow Depth 8.5" Hydrocarbons COMMENTS: ARSENIC 02/24/92 0.01 5 mg/l_ 0.999 1 05.9% All method blanks < MDL BARIUM 02/24/92 1 2 mg/L O. 999 1 00.0% Unfiltered samples were CADMIUM 02/24/92 0.002 mg/L O. 990 1 22. 9% 87.2% ......... acid digested for Total CHROMIUM 02/24/92 0.020 mg/L 0.999 81.6% 93.0% Recoverable Metals 02/23/92. LEAD 02/24/92 0.01 2 mg/L, 0.999 1 09.3% ,,, MERCURY 02/24/92 <0.001 mg/L 0.999 102.0% 102.0% * RPD Relative Percent Difference SODIUM 02/24/92 3 mg/L 0.999 1 03.0% 1 00.0% D1 --- I st Result D1 -D2 POTASSIUM 02/24/92 1.6 mg/L 0.999 78.0% D2-- 2nd Result X1 O0 ........ ZiNc 02/24/92 0.1 mg/L. 0.999 1 04.4% ' 1 00.0% (D1 + D2/2) ALUMINUM 02/24/92 7 mg/L 0.992 86.0% 1 01.0% CHLORIDE 02/23/92 "2.6 mg/l_ ' 0.999 1 08.0% 1.6% ,. SuEFATE 02/23/92 2.6 mg/L 0.999 .... 1 03.0% 3.2% ::KtC: ':EAB ::I::AR~30 :KL ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: SALINITY Sampled 2/2.2/92 1 225 hr 41 8.1 by RWN T. Petroleum Snow Depth 7" Hydrocarbons 02/23/92 < 0. 2 ppt 02/28/92 2. 5 mg/L :i::::lnStcumei~t::::: n/a O. 999 :i:qAiCheck:Std:: 98.6% 91.6% :::: M~td-X::Spike::: COMMENTS: All method blanks < MDL. O2/28/92 S.J.Barnsley/Stephen Rae KIC LAB Manager ARCO Alaska, Inc. Post Office Box ~u0360 Anchorage, Alaska 99510-0360 Telephone 907 263 4614 D. J. Ruckel KRU/CI/NV Drilling Manager March 6, 1992 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission (AOGCC) 3001 Porcupine Drive Anchorage, Alaska 99501-31 92 Re: Notification of Accidental Loss of Gas ARCO Cirque #1 Commissioner Johnston' ARCO Alaska, Inc., in compliance with 20 AAC 25.205 requiring notification of accidental loss of oil or gas, hereby submits the attached report concerning the blowout which occurred at the ARCO operated~ ell on February 12, 1992. With regard to compliance with 20 ACC 25.205, Subparagraph (a), ARCO (Bret Allard) notified AOGCC Commissioner Lonnie Smith at 10:00 PM on February 12, 1992 that an accidental release of natural gas had occurred at the Cirque #1 Well location. The AOGCC was subsequently advised and consulted through both its on-site representative and its Anchorage office. With regard to compliance with 20 ACC 25.205, Subparagraph (b), ARCO is aggressively pursuing its on-going review of the blowout event. Therefore, at this time it is difficult to provide a definitive report. With this in mind, ARCO requests that the AOGCC treat the attached report as preliminary. We propose to make a final report following review of causes and identification of preventive measures. ARCO will request confidentiality for this final report under 20 AAC 25.537. The final report would include items such as probable source of the gas flow, failure analysis of the divert lines and recommended equipment or procedural changes to prevent this incident from recurring. If you have questions or require any additional information, please contact Wayne McBride at 263-4962 or myself at 263-4614. Sincerely, MJS/RI 'Is ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company RECEIVED Alaska 0JJ & Gas Cons, Commission Anchorage 1) 2) 3) 4) 5) 6) Notification of Accidental Loss of Oil or Gas Cirque #1 As per 20 AAC 25.205.(b) Time of incident February 12, 1992 at 1930 hrs. Location where incident took place Cirque #1, 15 miles southwest of the Kuparuk River Unit 2M pad, more particularly in the NE/4, Section 20, T9N, R7E, U.M. Volumes of crude oil and natural gas lost No crude oil was observed at any time during the incident. Dry, natural gas was lost to the atmosphere. It is difficult to provide a meaningful lost gas volume for several reasons; 1.) Safety concerns prevented consistent on-site visual observations of vented gas, 2.) Flow rates fluctuated widely throughout the blowout period from February 12 at 1930 hrs. until the well was killed with mud on February 29 at 1200 hrs., and 3.) It is extremely difficult to estimate lost gas volumes through the open 10" divert lines. Cause of the loss A shallow gas flow occurred before surface casing was set at Cirque #1 resulting in a divert situation. The flow continued uncontrolled for 17 days. Actions taken and planned to prevent further loss The well was successfully killed on February 29, 1992 by pumping down the drill pipe and loading the hole with mud to overbalance the gas reservoir pressure. A relief well was also drilled in case the "top kill" method did not succeed. Equipment or procedural changes to prevent loss from recurring Any and all equipment and procedural changes will be determined based on our review of the cause of the incident. We propose to make a final report following review of causes and identification of preventive measures. We will request confidentiality for this final report under 20 AAC 25.537. RECEIVED MAR - 6 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage Anchorag. '~ska F~. ~rt Iden ~' Phone 263-4300 March 2, 1992 TO: Russ Douglass- AOGCC Thank you for lending us your video of the Cirque 1 that contains footage shot over the period February 13-21, 1992. We do not see anything on the video that could be considered confidential from an exploration standpoint. We are letting Channel 2 know about the tape mix-up. Since the well was killed on Saturday, we will not be furnishing them with a copy. R. Iden ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 300t PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 6, 1992 Richard F. Morgan Regional Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well Name: CIRQUE #1 ARCO Alaska, Inc. permit No: 92-09 Sur. Loc. 1014'FNL, 1874'FEL, Sec. 20, T9N, R7E, .UM Btmhole Loc. SAME AS ABOVE Dear Mr. Morgan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. , Blowout prevention equipment (BOPE).must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-360~. David WK Johnst~n' Chairman Alaska O~~d.~s Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. AIJ~, ~, OIL AND GAS ~SERVATION COMM~,..,~ PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill __ J lb. Type of Well Exploratory ~ Stratigraphic Test . Development Oil _ Re-Entry__ Deepen --I Service _ Development Gas __ Single Zone_ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc, KB ht above sea level: 160, Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL-375076 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1014' FNL, 1874' FEL, Sec. 20, T9N, R7E, UM N/^ Statewide At top of productive interval 8. Well number Number Same CIRQUE #1 #UG30610 At total depth 9. Approximate spud date Amount Same 2-10-92 $500,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1874 feet 5.0 Miles 5099 acres 8000' RKB feet 16. To be completed for deviated wells N/A 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth feet Maximum hole an~lle Maximum surface 1396 psil~ At total depth (TVD) 3448 pslt~ 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling ~.en~th MD TVD MD TVD (include sta, e dataI 17.5" 16" N/A B, API 5 _ PEB 80' 35' 35' 115' 115' Permafrost ~routin~ 12.25' 9.625" 36.0# J-55 BTC 2365' 35' 35' 2400' 2400' 460 sx AS III, 200 sx "G" 8.50" 7.0" 26.0# J-55 BTC 7965' 35' 35' 8000' 8000' 220 sx "G" 19. To be completed for Redritl, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Sct°rnU~tuUcrla°lrR E C E IV E D Surface Intermediate Production ?_ 1 992 Liner Perforation depth: measured Alaska 0il & Gas Cons. C0rnm~ssi0~ true vertical Anchorage 20. Attachments Filing fee ~ Property plat X BOP Sketch ~ Diverter Sketch X Drilling program X Drilling fluid program X~ Time vs depth plot _ Refraction analysis X Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge i~ i? I / "'-/~'~fTiflle Regional Drillincj Encjineer Date Commission Use Onl~, Permit Number APl number Condiiions of approval Samples required x~..Y e s ~ N o' Mud log required ~ Y e s ~ N o Hydrogen sulfide measures~ Y e s ~ N o Directional survey required __ Yes ;>~ N o Required working pressure for BO~M; ..~ 3 M · __ 5 M; ~ 1 0 M; ~ 1 5 M Other: ~~I Approved by~~._~?'~';'L--~. ~ ~/"~ ~ ~', Commissioner the commission Date Form 10-401 Rev. 7-24-89~.~~ Submit in triplicale ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 17, 1992 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Cirque #1 CONFIDENTIAL Dear Commissioner Johnston, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory well, the ARCO Cirque #1, on State lands near the western boundary of the Kuparuk River Unit. ARCO will act as operator for itself in evaluating acreage previously leased in State of Alaska Lease Sale 70A. The proposed well location is approximately 5 miles southwest of the ARCO Bermuda #1 well drilled in 1991 as shown on the attached map. ARCO proposes using Doyen Drilling, Inc.'s Rig 14 to drill this well during the winter of 1991-92. ARCO Alaska, Inc. as operator of the exploration well Cirque #1, requests exemption for Hydrogen Sulfide measures. This well is located approximately 12 miles southwest of Kuparuk 2M pad. No formations containing hydrogen sulfide are expected to be encountered in this well. The total depth for the well is 8000' which will penetrate the Kuparuk formation but will not penetrate the Lisburne formation. Enclosed find the information required by 20 AAC 25.005(c). The Commission is requested to keep confidential the following attachments to this permit application which are drawn from research and data proprietary to ARCO Alaska, Inc.: Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program If you have questions or require any additional information, please contact Tim Billingsley at 265-6575 or myself at 263-4970 in our Anchorage office. Sincerely, ~, Richard F. Morgan Regional Drilling Engineer RECEIVED J?,,N 1 992 Alaska Oil & Gas Oons. comm~sS~O Anchorage CONFIDENTIAL PROPOSED DRILLING PROGRAM ARCO CIRQUE #1 (Per 20 AAC 2S.005(c)(10)) RECEIVED Alaska Oil & Gas Cons. Commissior~ Ar~chorage Well Plan CONFIDENTIAL Cirque #1 (All depths are measured from RKB unless otherwise noted) 1. Move in and rig up Doyon 14. 2. Install diverter system on pre-set 16" conductor. . Drill 12-1/4" hole to 9-5/8" surface casing point at 2400'. Haul all drill cuttings and excess mud from this well to Kuparuk River Unit 2M pad for disposal in KRU Injection Well #2M-23. 4. Run and cement 9-5/8" 36#, J-55, BTC casing. 5. Install and test BOPE. Test casing to 2000 psi. 6. Drill out cement and 10' of new hole. Perform leak off test. 7. Drill and core 8-1/2" hole to 7000' TD. 8. Run the following open hole evaluation logs from TD to the 9-5/8" casing shoe: . Phasor DIL/FDC/CNL/MLOG/SP/GR (TRIPLE COMBO) LSS/EPT (Rxo Iog)/GR SHDT Dipmeter Rotary SWC Percussion SWC RFT (including fluid sample) RECEIVED AJaska OJJ & Gas Cons, Commission If the logs provide sufficient encouragement to testing an intervaI,A~l~0i~ cement 7" 26#, J-55, BTC casing. (Isolation of any hydrocarbon zones present w~l be performed.) Pressure test casing to 3500 psi. 10. Run cased hole Iogs(CBL). 11. Test well by setting production packer in casing at top of interval of interest and sting in with tubing-conveyed perforating guns, test tools and 3-1/2" tubing to surface. Include appropriate downhole flow control devices in test string. 12. With the tubing secured in the rotary slips and the pipe rams closed around it, nipple up 5000 psi test tree and manifold. Pressure test tree, manifold and test string. 13. Test by perforating underbalanced and flowing up the tubing and through the surface testing facilities. Test liquids will be stored in tanks on the drilling location and pumped back into the reservoir or down the 9-5/8" X 7" annulus after testing. Gas is to be flared. Testing will involve alternating flow periods and shut-in periods. Individual intervals may be tested separately or concurrently. 1 4. After completion of testing, kill well and remove test string and packer. 15. Using drill pipe as the work string, squeeze all open perforations and abandon well per 20 AAC 25.105. 1 6. Install well abandonment marker per 20 AAC 25.120. 17. Rig down and move rig to next drilling location. Thoroughly clean and abandon the ice pad and ice road on the way out. CONfiOEf TIAL PRESSURE ANALYSIS ARCO CIRQUE #1 (Per 20 AAC 25.005(c)(7), as required in 20 AAC 25.033(e)) RECEIVED Alaska Oil & Bas Cons. ,Som[n[ss~O~ Anchorage CIRQUE #1 PRESSURE ANALYSIS CONFIDENTIAL A pressure analysis was performed for this well using site-specific seismic data and offset well information from the well in closest proximity to the planned drilling location. The closest offset well is the ARCO Bermuda #1. The Bermuda well, drilled last winter, is located 5 miles northeast of the Cirque #1 location as shown on the attached map (Attachment #1) The Cirque well is intended to test the Kuparuk "C" sand. This prospect is thought to lie in an erosional Iow on the Lower Cretaceous Unconformity (LCU). This erosional Iow may be similar to encisements documented within the Kuparuk River Field at Drill Sites 1L and 2K. The Cirque prospect was recognized on seismic data where truncation of seismic events at the LCU are significantly below the top Kuparuk reflector, indicating thick Kuparuk "C" sand. Seismic data indicate no barriers to pressure communication between the proposed well and the Bermuda well. Since Bermuda experienced normal geopressures, unexpected trapped geopressure should not be a problem at Cirque. This is verified by the Interval Transit Time vs Depth plot (Attachment #2). The only trend reversals on this plot occur at 4000' and 7000' which can be explained by a change in lithology with increasing porosity at these two depths. With no indication that any anomalies exist, mud weight and fracture gradient information for the Bermuda well was extrapolated to the Cirque site. The same kind of information for the Union Kookpik well to the northwest was used, but not given as much emphasis owing to its distance from the proposed well. Attachment 3 contains the mud weight and fracture gradient information from the Bermuda well. Attachment 4 indicates the anticipated hydrostatic, mud and fracture gradients for Cirque as inferred from wells previously drilled west of the Kuparuk River Unit. The Cirque gradients are conservative, using the highest of the offset mud weights and treating formation integrity tests as actual leak-offs. RECEIVED ' ..... ATTACHMENT 1 '- ....... :s,.cJA'" ..... ,,--C[7!'t{F!,iJE TIAL 1 [ . ",~t' ''I '' '''~' ~ ....... : ~--~. ~-" I ~ ~RE-¢~'~~L'~',~.-:'~':.' ,~;,,,. · " ' ," , Iceberg ~1 .,- .... - .... ;.~ ~,.. ~ . ,r~ . ' ...... ~,. ro osed ,- ' [' .:,,~.~" , ~ . 2A PAD UNION ,.. :"'_.' .. (P P ~- ': ';'-';: ~-:-'' r-: --'- 2H PAD ' '? '~ :~':'i' ~'."*' ', ' ' t ' ,t ,~': t.,.:'-. . :- ~ [ "..': ,o · · '"~:_,:-- .'v . .~ ' ,- ~ ',-': '. ' , ' · . ~K PAD .- ~. ~. ..,,% . ..t . - , : . ~ .~ . . ~ ,: '*~-- . .. . . .:,, ........,...,->,. ,. ,,.._.,., . .. ? -"¢,~ :,j::: · -. <. ' ?,~ .- .... ¢.-. -, ,~ ' . ; ~,~S ',." .,.' ~ .,:", - .,';'.'-: ' - '-';*.':'-'.'4'~ . Tarn ~1 : ::~..:;~" '::-"--:>-- >':'.. ' .... % ....~¢':?~v~-:% ' ':- ~(Proposed) ;__.::" ' :,...:-': .. ~.~ ,:. ' ', ...':..Q'..'- ~-. ;:.-.'. ':~.. ,:;-:'-:-:' .. . . :~.- , . . .. :...+~,. :' ,~' :~: ~',,' i :~ -- ~, ..... ~ ' '.,,,' :-: - t,:::.' - :' - '": ":,<: ',: : " _ i:::: ,? -.: ,- , , ~, ~ ........ ..,. .. ., ~.~ ~,, ~., ( ,-- . : ,., ,.... . :....- :.: .... ..:...~_--:,._~:.~ .> ,. :.- ~ .. -::<., < ,,: ,. -1000 -2000 -3000 g23 -4000 ¢3. -5000 -6000 -7000 -8000 -9000 VELOCITY ANALYSIS FOR CIRQUE #1 WELL (ARCO SEISMIC DATA: SEFL 521 sp 627-623 0 ~. 100 1000 Interval Transit Time (micro sec/' -1000 -8OOO 8 'l"l l lll I i I 1[_1 I I I I I I I I I I I t I ARCO BERMUDA .............. iMUD WEIGHT CURVE .......................... :: ~,, .................. ~ ....... .......... , .= ........... ....... ~. ~, . ~ J 18 9 10 11 12 13 14 15 16 17 MUD WEIGHT -1 000 -2000 -3000 -4000 -5000 -6000 -7000 -8000 -9000 8 g 10 '11 12 13 14 15 16 17 MUD WEIGHT (ppg) ITl Z -.-I CONFIDENTIAL DIAGRAM AND DESCRIPTION OF DIVERTER SYSTEM TO BE USED ARCO CIRQUE #1 (Per 20 AAC 25.005(c)(5)) R~C~[VED Alasl(a Oil & Gas Cons. Ar~chorafie DIVERTER SCHEMATIC ARCO CIRQUE #1 CONFIDENTIAL 10", 150 psi Hydraulic Valve I Flowline I I I HYDRIL-GK 600, 20" Annular Preventer 20", 2000 psi Spool 10", 150 psi Hydraulic Valve ,/ 10" Outlets 16", APl 5L Grade B Conductor RECEIVED Alaska Oil~ ° Gas Cons. Ancho~'ago ARCO Alaska, Inc. requests approval of this diverter systemas a variance from 20 AAC 25.035(B) CONFIDE TIAL Per 20 AAC 25.005(c)(3): DIAGRAM AND DESCRIPTION OF BOP EQUIPMENT TO BE USED (As required in 20 AAC 25.035(a)(1)) AND INFORMATION ON MAXIMUM PRESSURES (As required in 20 AAC 25.035(d)(2)) BOP SCHEMATIC ARCO CIRQUE #1 13-5/8", 5000 PSI CONFIDENTIAL I I I 1 I I I I I I I I I I I I I 3 I RECEIVED Alaska Oil & Gas Cons. Cot Anchorage See listing of individual components on following page. ARCO CIRQUE #1 13-5/8, 5000 PSI BOP COMPONENTS CONFIDENTIAL o . . . 13-5/8", 5000 psi WP, Hydril annular preventer with companion flange to bell nipple. Single 13-5/8", 5000 psi WP, Hydril MPL blowout preventer fitted with pipe rams. Top preventer fitted with blind Double 13-5/8", 5000 psi WP, Hydril MPL blowout preventer. shear rams, bottom preventer fitted with pipe rams. 13-5/8", 5000 psi WP drilling spool. Choke Valves: 5. 4-1/16", 5000 psi WP Demco TC manual valve. 6. 4-1/16", 5000 psi WP Shaffer B hydraulic valve. Kill Valves: 7. 3-1/8", 5000 psi WP hydraulic valve 8. 3-1/8", 5000 psi WP manual valve PRESSURE INFORMATION ARCO CIRQUE #1 The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Cirque #1 well. Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure D r illi ng ¢in3 (ft, RKB) ¢lbs/gall {'lbs/gal) (psi1 (psi~ 1 6 1 1 5 10.9 8.7 52 53 9-5/8 2400 13.3 9.3 1161 1396 7 8000 Procedure for Calculatin0 AnticiDated Surface Pressure (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB 2) ASP = FPP - (0.11 x D) where' FPP = Formation Pore Pressure at the next casing point ASP Calculations 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.11]D [(10.9 x 0.052) - 0.11] x 115 53 psi ASP= FPP - (0.11 x D) = 1161 (0.11 x 2400) = 897 psi Aiaska Oil & Gas Cons. Comr~'~s$ior~ Anchorag~ , Drilling below surface casing (9-5/8") ASP -- [(FG x 0.052) - 0.11]D = [(13.3 x 0.052) - 0.11] x 2400 -- 1396 psi ASP-- FPP - (0.11 x D) = 4243 - (0.11 x 8000) = 3363 psi CONFIDENTIAL Casina Performance Properties Size Weight (in) (Ib/ft) 16 9-5/8" 36 7 26 Grade a~ APl 5L J -55 J -55 Cnxn PEB BTC BTC Internal Collapse Tensil Strength Yield Resistance Joint Body (psi) (psi1 (1000 Ibs~ ConductorCasing 3520 2020 4980 4320 639 564 490 415 Casing Setting Depth Rationale 1 6" 115' RKB 9-5/8" 2400' RKB 7" 8000' RKB Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to next casing setting point. Production casing to be set only if well is to be tested or the open hole below the 9-5/8" casing seat dictates an additional string of casing. Alaska Oil & Gas Co,,o. Anchorage CONFIDENTIAL PROPOSED CASING AND CEMENTING PROGRAM ARCO CIRQUE #1 (Per 20 AAC 25.005(c)(4)) Oil ,& Gas Coi~s, I I I I I I I I I I I I I I I I I I F:;:'*.:: ARCO ALASKA, INC CIRQUE #1 CASING SCHEMATIC CONF!DENTIAL 16", GRADE B, APl 5L CONDUCTOR @ 115' RKB ,-.:;:.:.. j 9-5/8", 36#, J-55, BTC -; SURFACE CASING @ 2,400' RKB CEMENTED TO SURFACE TOP OF CEMENT @ APPROX 6400' RKB 7", 26#, J-55, BTC PRODUCTION CASING @ 8,000' RKB ^i~s~<a Oil & Gas Cons. Comrn[~sion ~,nchora~e Cementing Program Cir(]ue #1 9-5/8" Surface Casino Casing Size: 9 - 5 / 8" Hole Size: 1 2 - 1 /4" Depth: 2 4 0 0' Top of Cement: Surface Excess Calculated: 50% (Lead Slurry Only) BHT (Static): 65°F BHT (Circ): 50°F ,,glurry Components and Properties: Preflshes' Lead: 80 bbl water 460 Sx Arctic Set III cement Slurry Weight' Slurry Yield' Thickening time: 12.1 ppg 1.94 cu. ft./sk 4+ hrs. 200 Sx Class G with 2% CaCI2 Slurry Weight: 15.8 ppg Slurry Yield: 1.15 cu. ft./sk Thickening time: 3-4 hrs, CONFIDENTIAL Alaska Oil & Gas Co~s. Anchora§a 7" production Casing Casing Size: 7" Hole Size: 8- 1 /2" Depth' 8 0 0 0' Top of Cement: 6 4 0 0' Excess Calculated' 1 5 % BHT (Static)' 1 70°F BHT (Circ)' 112°F Cementina Proclram -- Cirque #1 CONFiDEnTIAL Slurry Components and Properties: Preflushes' Tail: 70 bbls ARCO spacer 220 Sx Class G with 0.8% D-127, 4% D-53, .05 gal/sk D-135, 3% KCI Slurry Weight' 15.8 ppg Slurry Yield' 1.15 cu. ft./sk Thickening time: 3-4 hrs. CONFIDENTIAL PROPOSED DRILLING FLUID PROGRAM and DRILLING FLUID SYSTEM DESCRIPTION ARCO CIRQUE #1 (Per 20 AAC 25.005(c)(6)) ARCO ALASKA INC. C_irque Condensed Pro ram HOI. E DENSITY PLASTIC YIELD lO SEC IO HIN FLUID PER CENT HUD SIZE (PPG) VISCOSITY BH VISCOSITY POINT GEL :: GELS : LOSS SOLIDS TYPE 8.7 1 75 9.0 1 4 35 4~ 1 2- 1/4" to to to to to 1 5+ 2:0+ NC to SPUD MUD 9.6 125 9.5 8 20 8~ 8perate all solids removal equipment to maximum potential producing the driest discharge possible. Treat out calcium ,~ith Soda Ash. Use Benex after first bit bentonite extender. [;':; '.i;' ;';.:;:.." :' :' :':' :':' :':' :':' :': ':' :' :' :' :':' :' :' :': ': ':' :4. :-:. :.:. :.;. :.:. :.:. :. :. :.: .: .: .: .:. :.: .: .:. :. :. :4-:.:. :4. :4. :.:. :. :. :. :. :.: .: .: .: 4. :-:. :. :. :.:. :. :.: .:. :.:. :.:. :.: .:. :. :.: ~:-: .: 4. :.;~:.;:;. :; ;4. :.;. :.; ,: .: .;. :.: .; .: .: .:. ;. :.: ~: 4 o: 4° ?: o: .?: o:,;-: 4 .: .: .:o :4. :0 :. :. :4 ~: 4° :' :o: 4' ?;' ;4. :.: 4 ;277: '; ,: o:::o :-:o :-:o :' :4o :o: ':':/ SET ' Cl - ~'/8" CASING ~:~:::::!~:::::::::::::::::::::::::::::::::::::::::::::::::.":::::~:::::::::::::::!::~:::!:::::::::::~:::::::::::::::::::::::::::::!::::?~::::::::!~::!:::::!:::::::::!:!:::::::::!:::!:::2::?.::::::::::::!:2:::::::: ~.~ 40 9.5 6 8 5+ 8+ I0-12cc 8- I / 2" to to to to to at at I owe red to to NEW D P. I L L I O. ~ 45 1 0 1 5 1 4 TD TD 6 cc 1 2~; Operate all solids control equipment to keep solids to a minimum. Begin to lower fluid loss b9 7,000' FID' have <6¢c bg TD. Run centrifuge on enhanced mode to keep mud '.,~eight and rheologg in line. Av'uid use of lignosulfonate, u,ing CF Desco instead. Run bland pH as much as possible. Begin New Drill additions 500' t,) 750' abo~,e Kingak. ~: :::: :: :::: :: :: :: !:::':'. :: :: :::: :::: :::::: !: :::::: ::::}: !i~'; :::: ::':::::: :: :::: ::: ::: :: :: ::: ::::::::::::::::::::::: ::::¢:::::::: :::: ::::: ~:.':; ~'_~?!:!:: :::!:: &':!::::;: ::;: ;:::;::: ::!: ::2 :::!:' :_ :::::: !: :::::: :::::::: :: ::;i:::::;:' :.:: ::::'~!:::::;:¢i: ;:-:-: ::! ::::: '; ;:;: :: :::::: :::: :::~: ::::::::: :_:::2: :: :: !: :?.:!: :?.; !?.:':': ::'~:: :'.iU: ::: ': ::': :: :_:] Complete Log.qi ng and Testi n§ ARCO .A.~AgK_%. INC. _C !~RQUE__# ! INTER~A~L ~0LE SIZE; CASING_$~:_ CONDUCTOR: MUD TYPE: . 0 - 2,400' ] 2-1/4" 9-5/8" 16" Set Prior to Spud Spud Mud MUD P.ARAMETERS WEIGHT: VISCOSITY: DH: PV: YIELD POINT: FLU/D LOSS: 8.7 - 9.~ PPG 125 - 175 Sec/Ot 9.0 - 9.5 10 - 14 20 - 30 N.C. For the purposes of this program a 500 barrel active system will be used in all calculations. Prior to spud, strap pits and trace guns, discharge and suction lines, etc., in order to ascertain pit capabilities and liabilities. Fill the pits with fresh water and check both chloride and calcium levels. Treat out excessive calcium with small additions of Soda Ash (1/2 - 3/4 Dpb) until +40 DDm. ARCO's Cirque ~1 Interval: 0' - 2,400' For the first bit run mix the surface system to maximum capacity adding Milqel or sufficient quantity (25 - 30 ppb) to yield a viscosity of +175 sec/at. The 300f vis needed for infield drilling should be unnecessary here due to the decreased size and amounts of gravel. Prior to spud run this surface system briefly through the solids control equipment checking for leaks, etc. Drill ahead maintaining volume and sufficient yield point for good hole cleaning. Viscosity and yield point may be dropped back depending on hole conditions as surface gravel subsides. A viscosity of 100 sec/qt should suffice once it's determined that nothing extraordinary is occurring. Keep mud weiqht at or below 9.2 - 9.3 ppg with water additions and solids control equipment. Run all solids control equipment as necessary to keep sand content ~ 1% to improve the quality of the mud and reduce wear on pumps. Ben Ex may be used at a 5:1 ratio with Milgel as a bentonite extender and supplementary viscosifier after the first bit run. Run and cement 9-5/8" casing. ARCO's Cirque ~1 Interval: 0' - 2,400' ANTICIPATED PRODUCT USAGE FOR 12-1/4" HOLE PRODUCT Milgel Soda Ash Ben Ex Mil-Bar Q~NERIC NAME Bentonite Soda Ash Acrylic Polymer Barite (wt. pills for trips AMOUNT UNIT PRICE 275 SX 19.50/100# 8 SX 38.40/100~ 20 SX '16.75/ 2# 50 SX 17.75/100# ARCO's Cirque #1 INTERVAL: 2,400' - 8,000' HOLE SIZE: 8-]/2" CASING SIZE: 7" MUD TYPE: Low Solids Non-Dispersed (New Drill) MUD PARAMETERS '~'-~:,'~'~ ~:~'~ .~ WEIGHT: VISCOSITY: pH: PV: YIELD POINT: FLUID LOSS: ~.~ -10.6 PPG 40 - 45 Sec/Qt 9.5 - 10.0 6 - 15 8 - 14 10 - 12 CC/30 Min API, Reduced to ~ 6 CC/30 Min AP1 Prior to Kuparuk Formation For the purposes of this program it will be assumed that the rig chosen will have a desilter/mud cleaner unit as well as a centrifuge. In order to maintain the desired mud properties, in particular when a little deeper, i.e. drilling the Kingak, this equipment will be necessary. While nippling up, the surface system should be evaluated. If the mud is highly solids contaminated then the pits should be dumped and cleaned. Maintaining strict observance to solids control in the 12-1/4" hole will help avoid disposing of the entire system. A portion of this mud should be able to be reconditioned through the solids control equipment and diluted to prepare a low solids non-dispersed system. CONFIDENTIAL ARCO's Cirque ~1 Interval: 2,400' - 8,000' This system is classified as L.S.N.D. more because of a lack of dispersant additives than the resulting mud properties. A classic L.S.N.D. would have inverted PV/YP ratios, i.e. 1:2, etc. We have chosen to deviate from this system to a certain extent because a classic L.S.N.D. is simply to reactive for our purposes. We wanted the protective non-damaging benefits of this system with a more established rheologica] control. After treating out the calcium in the make-up water with Soda Ash, add Mi]Gel for 12 - 15 ppb. Add DrisDac (Regular or Lo depending on desired rheological properties ) at 1/2 - 3/4 Dpb for fluid loss and sol ids encapsulation. Slowly add Caustic Soda to raise the pH to 9.5. If necessary add XCD Polymer at 1/2 ppb or until viscosity is 40 - 45 sec/gr. This is an expensive product and should be used sparingly. Lastly add Mil-Bar to bring the weight to desired specifications. Other holes in this area have successfully drilled out with 8.7 - 8.8 ppg so barite additions will probably be minimal. Prior to drilling out the 9-5/8" casing shoe pretreat the surface with ] !:~l:~b Bicarb. Dump any heavily contaminated returns and treat out residual calcium while drilling ahead. COnFiDENTIAL ARCO's Cirque #1 Interval: 2,400' - 8,000' Drill ahead maintaining a L.S.N.D. system. Maximum use of solids control equipment and techniques are fundamental to operating this system to its opti]num efficiency. Running the finest shaker screens possible will act as a front line defense against solids build up. Any drilled solids eliminated on the first pass cannot recirculate, be broken down and lead to future rheological difficulties. Run the desilters as desilters, discharging the underflow of the cuttings bins. If maintaining volume and/or weight does become a problem, switch the unit to the mud cleaning mode temporarily. Run only 200 mesh screens on the mud cleaners to avoid recapturing any coarse solids. Desilters should be operated so they are processing 120% - 140% of returns. Be sure that there is not excessive mud loss from the desilting units to minimize subsequent trucking. If losses occur switch units to mud cleaning mode. Add all water below the shakers and not through shaker spray bars so as not to wash in any unwanted drilled solids. Any intentional increase in weight should be done with Mil-Bar. Incorporation of native solids to use as a foundation for this system runs contrary to a low solids technology. With recirculation and the particulate breakdown that ensues, rheological control becomes increasingly difficult. This problem is compounded by the relatively high penetration and lack ot dispersing agents. '~' · CONF.I ENTIAL ARCO's Iceberg ~1 interval: 2,400' - 8,000' Aias!{a Oil & Gas 6o~;s. Corc,~,ss~o~- Anchorat3e As native solids are incorporated and high yield points and pronressive gels develoD, this may lead to an increase in E.C.D. (Eauivalent Circulating Density) and result in loss of circulation in the event of encountering a sensitive formation. Any money saved through the use of native solids can be quickly lost. Loss of circulation has not been a significant problem in this area but t;hi~, e. hould be addressed. Solids-laden muds have .~'[~o DrOVer] t..O i)~l dJ~.iii~'iF~' to [_'~,_~ zot'~es via plt~qging pore throats, etc. Prior to entering the Kuparuk have the fluid loss at ~ 6 cc/30 min APl and maintain until TD of 8-1/2" hole. Historically the Kingak is a swelling and sloughing shale that has responded better to physical and mechanical rather than chemical inhibition. Increasing the mud weight in small increments (.1 - .2 ppg) will help reduce sloughing and the accompanying tight hole, fill, etc. However, this remedy has been only temporarily effective and further increased are generally necessary. Fortunately the Kingak ~n this area has not usually exhibited a fractured nature but increases in mud ~eiqht,especJaly when done in large increments, tend to shock the system and lead to loss of circulation. Depending on the formation's exhibited sensitivity, which with the Kingak can only be an on site determination, the yield point and circulation rates will have to be manipulated in order to control the E.C.D. E.C.D. can be adjusted through the manipulation of yield points, circulation rates, mud weights, etc. CONFIDENTIAL ARC()'s CirGue #1 Interval.: 2,400' - 8,000' These will be necessarily adjusted on location depending on hole conditions. It [las been found that the Kingak interval drills much easier when annular velocities are low, flow regimes flat, annular pressure looses low and therefore E.C.D.'s at a minimum. Increasing the yield point will help keep the flow regimes at flatter (laminar) levels. This in turn, however, yields a higher E.C.D. Running less pump decreases the annular velocity, uromotes laminar flow, decreases annular pressure losses and lowers E.C.D.'s. }{ere again, though, you will have to maintain circulation rates that adequately clean the hole. Essentially what is needed is to have your yield point adjusted so that it minimizes E.C.D. while still yielding flatter flow regimes at a predetermined circulation rate. AIl these parameters can be calculated on location to give a constant update to prevent and treat any problems that may arise. Maintain a L.S.N.D. system until close to TD of 8-1/2" hole. If the logging program is extensive and it's anticipated being out of the hole for extended periods of time, the system may be lightly dispersed in order to maintain rheological properties. Use only Uni-Cal S.E.A., a chrome-free lignosulfonate, or New Thin, a low molecular weight polyacrylate, for thinning purposes. Log, run and cement 7" casing. ARCO's Cirque #1 Interval: 2,400' - 8,000' ANTICIPATED PRODUCT USAGE FOR 8-1/2" HOLE PRODUCT Milgel Mil-Bar Dr ispac Caustic Bicarb Desco Soda Ash Soda QENERIC NAME Bentonite Barite Polyanionic Cellulosic Polymer Caustic Soda Sodium Bicarbonate Chrome Free Tannin Soda Ash AMOUNT UNIT PRICE 150 SX 19.50/100# 800 SX 17.75/100# 30 SX 191.00/ 50# 6 SX 33.25/ 50# 10 SX 41.20/100~ 12 SX 48.50/ 25# 6 SX 38.40/100# CONTINGENCY PRODUCTS Milchem MD Ethoxylated 8 Drums Alcohol Detergent Aluminum Stearate LD-8 in a Propoxylated 6 Cans Oleylalcohol Bore-Plate XCD Polymer New Drill Mil-Plug Gilsonite Resin 48 SX Xanthum Gum Polymer 4 SX Polyacrylamide 20 SX Polyacrylate Co-Polymer Walnut Hulls 20 SX 1.0 822.05/55 Gal DR 248.10/5 Gal Can 92.10/ 50# 188.50/ 25# 191.00/ 50# 23.10/ 50# CONFIDE DOYON 14 DRILLING FLUID SYSTEM DESCRIPTION MUD PITS AND CAPACITIES NIjmber Volume · Active Pits 5 970 bbls · Trip Tank 1 54 bbls · Pill Pit 1 43 bbls MUD FACILITIES AND EQUIPMENT · Shale Shakers: 4 each Brandt Tandem II screen shale shakers mounted on sand trap. · Mud Cleaner: 2 each Triflow Model 8-4 mud cleaners, each with eight 4" cones. Each mud cleaner charged by one Galigher Model HRO 200 5"x6" pump rated at 900 gpm at 12 ppg. · Centrifuge: One Pioneer Mark II, rated at 200 gpm. · Gas Buster: One each; 7' high x 5' wide, with one 3" inlet, one 10" gas exit line and one 13-3/8" mud exit line. 15 psi rated working pressure. · One surface mixing gun on Iow pressure pit system. · One Press-Weld cellar jet pump, rated at 75 gpm. - - - t 11 I I II P'!"!---! --- . I '"- I -- - ;. .; · M/DOLE I I I I -T-- I II I ! · I---I 1 o. .. I ' - ITEM (1) Fee (2) Loc ..... ** CHECK LIST FOR NEW WELL PERMITS ** D)TE, [2 thru 8] (3) Admin [~j~/~ E9 thru [10 & 13] (4) Casg ~."~,'~,~ /-"'.,~Z "9~ [14 thru 22] [23 thru 28] (6) Other [29 thr~:~ ]- (6) Addl geology' encj i neer i ng: , DWJ~ MTM/~--~_ LCS ~ RP~.~__~. BEW .__ RAD~t.I rev 03/29/91 jo/6.011 Lease & We ] 1 ~,, ~Z)/_ ,~ ]f,~"DT{~, , ~_~t~ u -~' REMARKS Is permit fee attached ............................................... 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. Does operator have a bond in force .................. ' ................. Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease n~nber appropriate .......................................... Does well have a unique name & nt~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~'~JO~. psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: YES NO J ,, 32. Are data presented on potential overpressure zones ................... //~ Are seismic analysis data presented on shallow gas zones ............. ,~_ If offshore loc, are survey results of seabed conditions presented... ~,~, . Additional requirements ............................................. ~ Additional remarks' INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,, , C~ O