Objectives/Scope Objective of this paper is to describe a methodology applied to overcome production logging challenges in a horizontal / deviated, low pressure and high water cut well in order to determine flow profile and zonal phase contribution. Method, Procedures, Process Conventional production logging with Electric wireline in the deviated / horizontal and low pressure wells is becoming a challenge. Measuring an inflow profile and identifying water producing intervals in low pressure high water cut wells require an improved methodology. Electric wireline conductor cable placed inside coiled tubing (CT) creates new opportunities for logging and induces well production while logging. Subsurface information obtained from recently drilled Jurassic wells indicates presence of hydrocarbon accumulation beyond present limit. A new well has been drilled and completed with 7 inch liner to prove the hydrocarbon in a new reservoir. The well was perforated in underbalanced condition and tested with Drill Stem Test (DST). There are four perforation intervals in the deviated profile. The promising four layered carbonate formations produced 100% water while lifting the well with Nitrogen. Acquisition of flow profile data in this well is vital for decision making. It was required to diagnose the contributing and non-contributing intervals to decide on the suitable remedial action. Low pressure with high water cut reservoir becomes a challenge in measuring inflow profile and identifying water producing intervals. Electric Coiled Tubing (E-CT) was used to convey the production logging tool while pumping Nitrogen (N2)to lift the well production to acquire inflow profile data. Surface well testing equipment was used to measure the surface flow rates. Shut-in survey and flowing survey were performed to identify presence of water behind casing, cross flow and water entry. Multi-finger Imaging Tool (PMIT) was used to measure the internal diameter of the casing strings to confirm the presence of the perforation intervals. Results, Observations, Conclusions Well production was induced by pumping N2 through E-CT while production logging. Inflow profile data was successfully acquired from a deviated, low pressure and high water cut well using production logging tool (PLT) attached with coil tubing. Production logging results showed that all of the water production is coming from the top part of the third perforation intervals. During Shut-in Survey, it was observed that no cross flow between the perforation intervals and no observation of flow behind casing above or below the perforation intervals. Furthermore, it was observed that the PMIT logs clearly proved the presence of all 4 perforation intervals. The data acquired using E-CT production logging confirmed the contributing and non-contributing intervals which provided a clear vision to take a remedial action. Novel / Additive Information For the first time in Kuwait, E-CT was successfully used to record flow profile in horizontal/deviated exploratory well while Nitrogen lifting. This successful application will help to acquire production logging in the wells with similar condition.

Testing and completing deep reservoir in the state of Kuwait is challenging due to high contrast in formation pressure over the 4,000 feet section (13,500' to 17,500'). Recently, a new structure located in the North-Western part of Kuwait area was drilled and tested with deep drilling rig. Formations in this deep structure have very low porosity and permeability with naturally fractured reservoir. During short term testing, wells produced oil and gas with unexpectedly very high H2S(20%-35%), the highest H2S content in any reservoir so far discovered in the state of Kuwait. Since the reservoir was rated as HPHT and sour, it was a challenging experience to test all the wells safely and successfully. Unfavorable conditions such as high pressure, high temperature, high H2S and CO2 content require special equipment, tools and treatment to test and complete exploratory wells.The targeted formations were perforated using deep penetration TCP guns, stimulated with emulsified/retarded acid, tested with Drill Stem Testing(DST) tools and sampling was done. Meticulous planning and testing strategies could overcome all challenges and high sour reservoir was successfully tested safely without any incident. The wells were flowed only for short period due to high sour nature of the reservoir fluid and safety reasons. However, data collected during short term testing helped in understanding production capability, fluid and reservoir characteristics which is vital for delineation/development of the new field. Methods developed, data obtained and expertise gained in testing and completing high sour wells will be useful for the future development of sour gas reservoir.Aim of this paper is to describe the actual challenges encountered and lessons learned during testing and completion of hostile environment wells. This paper also aim to present techniques and approach adopted to address the operational risk and HSE issues during perforation, Coiled Tubing, stimulation, well testing and sampling operations.

This paper discusses the outstanding performance achieved in a deep HPHT Jurassic formation drilled using Potassium Formate based fluid. This paper also describes methodology adopted for short term testing and stimulation of an exploratory well and finally the field results.Drilling and completion of deep Jurassic formations in the state of Kuwait is generally done with Oil Base Mud (OBM) weighted with Barite. During drilling, barite causes significant formation damage to the carbonates with natural fractures and it is essential to stimulate the well to evaluate the real reservoir potential. Formation damage is usually treated with matrix acid stimulation, however barite does not respond to acid. Kuwait Oil Company (KOC) was in search for an alternative drilling fluid causing relatively less formation damage and also responds to remedial actions. Potassium Formate brine with suitable weighting agent to achieve sufficient mud weight around 16ppg was selected for field trial in one of the exploratory wells. Formate based brine is a high-density Water Base Mud (WBM) which maintains rheological stability at high temperature and minimizes formation damage.Last 2,000 feet in 6" hole section of 18,000 feet well was drilled using 15.9 ppg Potassium Formate WBM. During short term testing, acid wash alone was sufficient to remove the formation damage and productivity has tripled which is unlikely in case of wells drilled with OBM.This case study shows how Potassium Formate based mud enhanced the productivity and reduced the testing time and cost. Based on the successful field test results, it is planned to drill future Jurassic deep formation with Potassium Formate based fluids in future.

Objective/Scope The main objective is to find a way to increase the well production and sustain the production by connecting the reservoir through several stages of fractures spaced throughout the horizontal drain hole. Method, Procedures, Process Exploratory wells targeting Mauddud reservoir were normally drilled vertically and stimulated in a conventional way using matrix acid treatment, which proved a good hydrocarbon potential, but with low productivity. A study was conducted in one the lower cretaceous reservoir (Mauddud) which recommended the option of drilling a horizontal well in the mentioned reservoir and applying multi-stage acid frac for productivity enhancement and sustainability. The target carbonate reservoir is tight, has a porosity of approximately 12-20% and permeability between 0.05 to 2 md. The first horizontal well for Maudddud reservoir was drilled up to a measured depth of 11,171 ft MD with a horizontal section of 2,752 ft. It was completed with swell packers and seven frac sleeves for multi stage fracturing job in the horizontal section. Designing and execution of multi-stage frac in a horizontal well is technically more challenging than the conventional vertical well. Minifrac was performed to find the fracture pressure, closure pressure and understand the net pressure needed to extend the fracture. Based on the mini-frac results, the main frac design was modified. Main Frac treatment was carried out in seven stages, each stage was performed individually and the fractured stage was isolated using frac balls with different sizes. Acid and gel mixing was performed continuously on location to enable continuous pumping operation, which minimized the time between stages. After a successful multistage frac treatment, the well was flowed back for cleanup and recovered all spent treatment fluid. Later Coiled Tubing (CT) with milling tool was used to mill the ball and seats to provide full bore access through the frac sleeves. Subsequently production logging tool (PLT) survey was carried out in horizontal section using CT to confirm the effective contribution from each stage. Results, Observations, Conclusions Horizontal exploratory well was drilled, completed and fractured successfully with seven stages led to a sustainable oil production after installing ESP. The flow results after the multistage frac showed that there is tremendous increase in production but with some decline. The PLT result showed the contribution profile for each stage and the cross flow status. Production enhancement and sustainability achieved from this well encouraged KOC to drill more horizontal wells for Mauddud reservoir with similar multistage completion and frac strategy to meet the production targets. Novel/Additive Information This paper highlights the well design, the effectiveness of multi stage fracturing, well performance analysis, lesson learned and results of the multistage completion & acid fracturing.

Objectives/Scope In 2014, number of exploratory wells were drilled and tested in Umm Niqa (UN) Field located in north Kuwait NE which approved a new discovery in Lower Fars (LF) reservoir. LF is unconsolidated, sub –hydrostatic- sand stone reservoir with highly sour and moderate corrosive environment (H2S 8% and CO2 4%). Subsequently additional wells were drilled to evaluate the production potential of UN field. With rig on location UN wells are completed with test (Progressive Cavity Pump) PCP and tested. During the initial testing period the PCP is run at different speeds to evaluate the well productivity, water cut, and determine sand-free draw down to enable selection of suitable completion PCP for production. Methods, Procedures, Process Well UN-X is one of the developed wells which is perforated in LF sand in overbalanced condition using 4-1/2" (High Shot Density) HSD guns with 0.83" entrance hole diameter at 12 shoots per foot. During initial testing with test PCP, the pump tripped due to high torque because of sand production (up to 60%). Five runs were performed to clean out the wellbore and repeated test PCP runs failed due to high sand production. Coordination between FDHO (Field Development Heavy Oil) and Discovery Promotion Team was conducted to perform quick sand analysis to LF sands from offset sand distribution since subject well has no available sieve analysis. Based on the outcome of sieve analysis, decision was made to utilize one of the available SAS (Stand Alone Screen) designed for LF sand in another field to control sand production. It was agreed by both teams to install SAS in the subject well to mitigate the sand problem and minimize cost due to NPT (Non-Productive Time) of the rig. SAS was installed and the potential zone in UN-X could be tested successfully with tubing PCP. No sand problem was observed during testing and after testing while clean out operation there was no sand. Results, Observations, Conclusions Well test showed an average liquid rate of 124 BFPD with 37% WC (predominantly completion brine). The well was put on production on November 2016 and producing till date without any sand problem. Novel/Additive Information This paper will include discussion on the approach used to select a sand control method for cold and heavy oil production. The results of sieve analysis was in the middle between sand screen and gravel pack but based on the team experience in sand control and the nature of heavy oil and its relatively low oil production rate, the decision was made to install SAS and that was proved to be prudent decision.